Alaska Logo
Department of Commerce, Community, and Economic Development
Alaska Oil and Gas Conservation
Commission
Loading...
HomeMy WebLinkAbout218-021MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Monday, June 13, 2022 SUBJECT:Mechanical Integrity Tests TO: FROM:Adam Earl P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL Hilcorp Alaska, LLC F-108 MILNE PT UNIT F-108 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 06/13/2022 F-108 50-029-23598-00-00 218-021-0 W SPT 4085 2180210 1500 751 757 750 747 4YRTST P Adam Earl 5/6/2022 MIT IA -MONO BORE 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:MILNE PT UNIT F-108 Inspection Date: Tubing OA Packer Depth 382 2006 1927 1906IA 45 Min 60 Min Rel Insp Num: Insp Num:mitAGE220509113840 BBL Pumped:2.2 BBL Returned:2.2 Monday, June 13, 2022 Page 1 of 1 9 9 9 9 9 9 9 9 9 9 9James B. Regg Digitally signed by James B. Regg Date: 2022.06.13 14:53:50 -08'00' Samuel Gebert Hilcorp Alaska, LLC GeoTech Assistant 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: 907 777-8337 Fax: 907 777-8510 E-mail: sam.gebert@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to 907 777.8510 Received By: Date: DATE: 10/01/2020 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 DATA TRANSMITTAL MPU F-108 (218-021) Injection Profile 07/06/2020 Please include current contact information if different from above. PTD: 2180210 E-Set: 34027 Received by the AOGCC 10/02/2020 Abby Bell 10/05/2020 Samuel Gebert Hilcorp Alaska, LLC GeoTech Assistant 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: 907 777-8337 Fax: 907 777-8510 E-mail: sam.gebert@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to 907 777.8510 Received By: Date: DATE: 10/01/2020 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 DATA TRANSMITTAL MPU F-108 (218-021) Injection Profile 06/30/2020 Please include current contact information if different from above. PTD: 2180210 E-Set: 34026 Received by the AOGCC 10/02/2020 Abby Bell 10/05/2020 Samuel Gebert Hilcorp Alaska, LLC GeoTech Assistant 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: 907 777-8337 Fax: 907 777-8510 E-mail: sam.gebert@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to 907 777.8510 Received By: Date: DATE: 10/01/2020 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 DATA TRANSMITTAL MPU F-108 (218-021) Injection Profile 05/14/2020 Please include current contact information if different from above. Received by the AOGCC 10/02/2020 PTD: 2180210 E-Set: 34025 Abby Bell 10/05/2020 Samuel Gebert Hilcorp Alaska, LLC GeoTech Assistant 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: 907 777-8337 Fax: 907 777-8510 E-mail: sam.gebert@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to 907 777.8510 Received By: Date: DATE: 10/02/2020 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 DATA TRANSMITTAL MPU F-108 (PTD 218-021) COIL FLAG 06/30/2020 Please include current contact information if different from above. Abby Bell 10/05/2020 PTD: 2180210 E-Set: 34024 Received by the AOGCC 10/02/2020 Samuel Gebert Hilcorp Alaska, LLC GeoTech Assistant 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: 907 777-8337 Fax: 907 777-8510 E-mail: sam.gebert@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to 907 777.8510 Received By: Date: DATE: 10/01/2020 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 DATA TRANSMITTAL MPU F-108 (PTD 218-021) COIL FLAG 06/29/2020 Please include current contact information if different from above. Data received by the AOGCC 10/02/2020, transmittal resubmitted 10/13/2020 PTD: 2180210 E-Set: 34023 Abby Bell 10/13/2020 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: ICD Closure Hilcorp Alaska Development Exploratory Stratigraphic Service 6. API Number: 7. Property Designation (Lease Number): 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071): 10. Field/Pool(s): 11. Present Well Condition Summary: Total Depth measured 11,961 feet N/A feet true vertical 4,107 feet N/A feet Effective Depth measured 11,955 feet 5,487 feet true vertical 4,107 feet 4,085 feet Perforation depth Measured depth See Schematic feet True Vertical depth See Schematic feet Tubing (size, grade, measured and true vertical depth)4-1/2" 12.6 / L-80 / TXP-SR 5,494' 4,086' Packers and SSSV (type, measured and true vertical depth)Liner Top N/A See Above N/A 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:777-8343 2. Operator Name Senior Engineer: Senior Res. Engineer: Collapse N/A 3,090psi 8,540psi Burst Surface Liner N/A 5,750psi 9,020psi 20" 9-5/8" 4-1/2" 4,104' 4,107' Junk measured Length 107' 5,658' 6,473' Tubing Pressure 0 N/A measured N/A Casing Conductor Size 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. 320-249 380 Authorized Signature with date: Authorized Name: David Haakinson dhaakinson@hilcorp.com STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 218-021 50-029-23598-00-00 Plugs ADL025509, ADL388235 & ADL025515 5. Permit to Drill Number: Milne Point Field / Schrader Bluff Oil Pool 3800 Centerpoint Dr, Suite 1400 Anchorage, AK 99503 3. Address: 4. Well Class Before Work: 0 Representative Daily Average Production or Injection Data 00 MPU F-108 Gas-Mcf 0 520 Oil-Bbl measured true vertical Packer 0 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 0 Casing Pressure WINJ WAG 0 Water-Bbl MD 107' 5,658' 11,960' TVD 107' Form 10-404 Revised 3/2020 Submit Within 30 days of Operations By Jody Colombie at 10:43 am, Jul 19, 2020 Chad A Helgeson 2020.07.17 15:20:30 -08'00' DSR-7/20/2020 SFD 7/20/2020 RBDMS HEW 7/20/2020 MGR21JUL2020 _____________________________________________________________________________________ Revised by: DAH 7/7/2020 SCHEMATIC Milne Point Unit Well: MPU F-108 PTD: 218-021 API: 50-029-23598-00-00 CASING DETAIL Size Type Wt/ Grade/ Conn Drift ID Top Btm BPF 20" Conductor N/A / X-52 / Weld N/A Surface 107’ N/A 9-5/8" Surface 40 / L-80 / DWC/C 8.75” Surface 5,658’ 0.0758 4-1/2” Liner 13.5 / L-80 / Hyd 625 3.85” 5,487’ 11,960’ 0.0149 TUBING DETAIL 4-1/2" Tubing 12.6 / L-80 / TXP-SR 3.833” Surf 5,494’ 0.0152 JEWELRY DETAIL No Top MD Item ID Upper Completion 1 2,325’ X Nipple MCX injection valve with .50 bean installed 7/7/2020 3.813 2 5,101’ XN Nipple profile: 3.725” No Go / 3.813 Packing Bore 3.725 3 5,482’ 8.25” No-Go Locater on Tieback Assy ([4] - 1” Ported Seal Stem) 3.960 4 5,494’ Tieback Shoe 6.180 Lower Completion 4 5,487’ Liner Top Packer (TVD= 4,081’) - 5 11,955’ WIV (Ball on Seat/ Closed) PBTD - OPEN HOLE / CEMENT DETAIL 42" ~270 ft3 12-1/4" Stg 1 – 370 sx Lead / 400 sx Tail Stg 2 – 267 sx Lead / 264 sx Tail (173 bbl surface returns) 8-1/2” Cementless Injection Liner in 8-1/2” hole WELL INCLINATION DETAIL KOP @ 100’ Max Hole Angle = 93.73° @ 9,791’ MD TREE & WELLHEAD Tree Cameron 4 1/16" 5M w/ 4-1/16” 5M Cameron Wing Wellhead Cameron 11” 5K x sliplock bottom w/ (2) 2-1/16” 5K outs GENERAL WELL INFO API#: 50-029-23598-00-00 Completed by Innovation 4/26/2018 Depth MD Depth TVD ICD/Swell Packer Detail 5,768’ 4,104’ Weatherford - ICD w/ 316L mesh, 16 port (3 open / 13 closed) 13.5# bxp 625 Wedge 6,029’ 4,107’ Swell Packer – Weatherford Genesis Swell Packer #8 6,581’ 4,117’ Weatherford - ICD w/ 316L mesh, 16 port (3 open / 13 closed) Closed 7/6/2020 (MBE to F-107) 6,882’ 4,111’ Swell Packer - Weatherford Genesis Swell Packer #7 7,151’ 4,102’ Weatherford - ICD w/ 316L mesh, 16 port (3 open / 13 closed) Closed 7/6/2020 (MBE to F-107) 7,208’ 4,102’ Swell Packer - Weatherford Genesis Swell Packer #6 7,882’ 4,101’ Weatherford - ICD w/ 316L mesh, 16 port (3 open / 13 closed) Closed 5/27/2020 (MBE to F-107) 8,350’ 4,108’ Swell Packer - Weatherford Genesis Swell Packer #5 8,655’ 4,118’ Weatherford - ICD w/ 316L mesh, 16 port (3 open / 13 closed) 13.5# bxp 625 Wedge 8,999’ 4,124’ Swell Packer - Weatherford Genesis Swell Packer #4 9,392’ 4,122’ Weatherford - ICD w/ 316L mesh, 16 port (3 open / 13 closed) 13.5# bxp 625 Wedge 9,737’ 4,108’ Swell Packer - Weatherford Genesis Swell Packer #3 10,092’ 4,093’ Weatherford - ICD w/ 316L mesh, 16 port (3 open / 13 closed) 13.5# bxp 625 Wedge 10,522’ 4,082’ Swell Packer - Weatherford Genesis Swell Packer #2 10,878’ 4,077’ Weatherford - ICD w/ 316L mesh, 16 port (3 open / 13 closed) 13.5# bxp 625 Wedge 11,263’ 4,088’ Swell Packer - Weatherford Genesis Swell Packer #1 11,825’ 4,098’ Weatherford - ICD w/ 316L mesh, 16 port (3 open / 13 closed) 13.5# bxp 625 Wedge Well Name Rig API Number Well Permit Number Start Date End Date MP F-108 CTU #6 50-029-23598-00-00 218-021 6/29/2020 7/7/2020 Well Shut in. MU BHA #3 - Inflatable straddle packer assembly with 33. 19' spacing between packers. PT to 248/ 3,565 psi. RIH to flag, correct depth, and set depth to COE of lower packer. Set straddle packer across #4 ICD (7,882' md) with upper packer at 7,859' and lower packer at 7,892' md. Attempt to burst rupture disc taking final pressure up to 6k psi. No indication of bursting the disc. Unable to pump H20 treatment. Release straddle packers and POOH. Found the rupture disc was burst, indicating that straddle packer assy was set in blank pipe or the sliding sleeve at ICD #4 is closed. Recovered both packers and all elements. MU and RIH with memory GR/CCL STP IPROF logging tools. Make dynamic passes from 8,200' to 5,600' and get stop counts between the top 4 ICD's while well on injection at 2000 bwpd. POOH. Shut off injection from Polymer skid and FP well with diesel. IPROF indicated ICD #4 is taking very little if any water. RDMO. No operations to report. 6/27/2020 - Saturday Well Shut in. MIRU SLB CTU #6 -2" CT. MU Baker MHA and Read memory GR/CCL logging tools. PT to 300/4,000 psi. RIH to 8,000' ctmd and log up to 5,000'. Stopped at 7,910' ctmd to flag pipe. POOH. Tie log in to Liner Tally, make -32' depth shift. EOP at flag is 7,866.98' MD. MU and RIH Baker inflatable straddle packer BHA. Stop at flag and corrrect depth to COE of lower packer. Drop 1/2" ball and Set Packers on depth to straddle ICD #4 at 7,882' MD. Pressured up to 6000 psi to burst rupture disc with no success. Release packers and POOH. Rupture disc did not burst. Possibility that set depth was deep and straddling in blank pipe. No packer elements were lost. Secure well and SDFN. 6/30/2020 - Tuesday 6/28/2020 - Sunday No operations to report. 6/29/2020 - Monday 6/26/2020 - Friday No operations to report. 6/24/2020 - Wednesday Hilcorp Alaska, LLC Weekly Operations Summary No operations to report. 6/25/2020 - Thursday No operations to report. Well Name Rig API Number Well Permit Number Start Date End Date MP F-108 CTU #6 50-029-23598-00-00 218-021 6/29/2020 7/7/2020 No operations to report. No operations to report. 7/4/2020 - Saturday CTU #6 Shift ICDs #2 and #3 to the closed position. RIH to 7,200' CTMD Put well on injection @ 2,000 bwpd. Allow well to inject for 20 minutes then S/I. Locate and shift ICD #3 @ 7,203' CTMD seen sleeve close but tool did not release as expected. Made two passes to confirm closed and caught profiled both times. Ran back in hole to 7,250' CTMD Brought well on injection targeting 2,000 bwpd. Contacted OE in town. Completed station stop for 10 min. Made up pass @ 120 fpm to 6,500' CTMD RIH back down to 6,700' CTMD and perform 10 min station stop. S/I injection and shift ICD #2 at 6,651' CTMD caught profile and seen shift and tool released at 5K over. Repeated a second time and cought profile and pulled 10k over, tool did not release. Brought well on injection targeting 2,000 bpwd. Contacted OE in town. Results are looking favarable. OE altered remaining program to include additional station stop above ICD #2 then reduce injection rate down well to 1,500 bwpd. RIH TO 8,800'. Perform up-pass at 120 fpm to 5,000'. POOH freeze protecting well with 35 bbls of diesel. Recovered good data. No flow indication of out flow at ICD #2 or #3 both are closed. 7/7/2020 - Tuesday 7/5/2020 - Sunday No operations to report. 7/6/2020 - Monday 7/3/2020 - Friday No operations to report. 7/1/2020 - Wednesday Hilcorp Alaska, LLC Weekly Operations Summary No operations to report. 7/2/2020 - Thursday No operations to report. 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: MBE Treatment 2.Operator Name:4.Current Well Class:5.Permit to Drill Number: Exploratory Development 3. Address:Stratigraphic Service 6. API Number: 7. If perforating:8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception?Yes No 9.Property Designation (Lease Number):10.Field/Pool(s): 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi):Plugs (MD):Junk (MD): 11,961'N/A Casing Collapse Conductor N/A Surface 3,090psi Liner 8,540psi 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: Operations Manager Contact Email:dhaakinson@hilcorp.com Contact Phone: 777-8343 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 Tubing Grade: Tubing MD (ft):Perforation Depth TVD (ft): COMMISSION USE ONLY Authorized Name: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL025509, ADL388235 & ADL025515 218-021 3800 Centerpoint Dr, Suite 1400 Anchorage, AK 99503 50-029-23598-00-00 Milne Point Field / Schrader Bluff Oil Pool Hilcorp Alaska LLC Length Size 4,107' 11,955' 4,107' C.O. 477.05 PRESENT WELL CONDITION SUMMARY 1,133 N/A 107' 107' 12.6 / L-80 / TXP-SR TVD Burst 5,494' MD N/A 5,658' 6,473' 5,750psi 9,020psi 4,104' 4,107' 5,658' 11,960' MPU F-108 David Haakinson Liner Top and N/A 5,487MD / 4,085TVD and N/A See Schematic 107' 20" 9-5/8" 4-1/2" 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: 6/18/2020 4-1/2" Perforation Depth MD (ft): See Schematic 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 11:17 am, Jun 11, 2020 320-249 Chad A Helgeson 2020.06.10 19:23:03 -08'00' gls 6/12/20 r: MBE Treatment SFD 6/11/2020 10-404 DSR-6/11/2020Comm q 6/16/2020 dts 6/15/2020 JLC 6/15/2020 RBDMS HEW 6/18/2020 Conformance Treatment Well: MP F-108 Well Name:MP F-108 API Number: 50-029-23598-00-00 Current Status:Injector (Shut In)Wellwork Unit:CTU (2), SL (1) Estimated Start Date:June 20 th, 2020 Estimated Duration:3days Reg.Approval Req’std?N/A Date Reg. Approval Rec’vd:N/A Regulatory Contact:Tom Fouts 777-8398 Permit to Drill Number:218-021 First Call Engineer:David Haakinson (907) 777-8343 (O) (307) 660-4999 (M) Second Call Engineer:Wyatt Rivard (907)-777-8547 (O) (509)-670-8001 (M) AFE Number: WellEZ Entry Required?Yes SBHP: 1,720 psig at 4,000’ TVD | 8.3 PPG EMW MPSP: 1,320 psig (0.1 ppg gas gradient) Max Deviation: 93.6° at 6,898’ MD Max Dogleg:7.5°/100’ at 4,876’ MD Last Tag:N/A. Original Drill PBTD @ 11,955’ MD Minimum ID:3.725” XN Nipple at 5,101’ MD Max Surface Treatment Pressure: 2,700 psig Brief Well Summary: MP F-108 is a Schrader Bluff injection well drilled and completed in the OA sand. On 4/28/2020, an apparent matrix bypass event (MBE) occurred between F-108 and F-107. An injection profile survey completed identified the ICD at 7,882’ MD taking approximately 33% of the injection flow at 2,050 BWPD. The remaining ICDs appear to be taking fluid at 5-10%. Attempts were made to shift the ICD sleeve, but were unsuccessful. Welding modifications were completed on the ICD and may have resulted in damage or binding of the ICD. Since the ICD at 7,882’ MD could not be closed, a conformance treatment is now needed on the well. Objective: 1) Complete GR/CCL and pipe flag for tie-in. 2) Pump MBE conformance treatment. 3) Install MCX valve and return well to injection. Notes: x Currently all ICDs are open. x Slowly move through ICD profiles with CT BHA. o All ICDs have 3.813” MIN ID and can be shifted. Sleeves are shift-up to close and should take 1,000-2,000lbs of force to shift. x Gel Conformance Treatment: o Proposal to use 8.7 ppg H2Zero to allow for ICD penetration and to reduce fracture potential. Risks: x Exceeding fracture pressure on CTU Job o Do not exceed 800 psig surface injection pressure or 2,000 BWIPD injection rate on source water. o Assuming a 0.66 psi/ft fracture gradient, do not exceed 2,700 psig at the sand-face with treatment pressure after accounting for frictional pressures. x Upsetting the facility: Note that offset producer F-107 may begin producing solids. o Shut in F-107 prior to pumping the H2Zero Product Note: ICD stuck open at 7882 ft (using straddle packer on CT to treat zone) Conformance Treatment Well: MP F-108 x Screen-out of the H2Zero in the ICD o If plugging of the ICD is encountered, PU CT to release straddle packers. PU and circulate H2Zero Gel product out of hole. Circulate bottoms up. Procedure: Part 1: CTU & Pumping Unit 1. MIRU flow-back tank and upright with at least 200 bbls of MPU Source Water. 2. MIRU CT unit. 3. Ensure BOP test has been completed within the last seven days. a. If BOPE test has not been completed in last 7 days, test BPE to 250 psig low / 2,500 psig high. b. No AOGCC notification required. c. Record BOPE test results on 10-424 form. d. If within the standard 7 day test BOPE test period for Milne Point, a full body test and function test of the rams is sufficient to meet weekly BOPE test requirement. 4. RIH with 2” CT with CTC, DBCV, carrier and memory GR/CCL for tie-in and 2” nozzle. 5. RIH to below ICD #4 to 8,000’ MD. 6. PU 7,910’ MD at 40 FPM. Flag Pipe. 7. POOH at 40 FPM for jewelry log to 5,400’ MD. 8. POOH to surface for BHA change. 9. Review GR/CCL data for tie in. Plan to set the lower treatment packer (mid-element) at 5’ below the 9’ ICD connection. 10. MU treatment BHA with 2” CT, CTC, and Baker Hughes Treatment BHA. 11. RIH to 8,000’ MD. POOH to tie into the flag pipe, GR/CCL tie in, and correction. 12. Confirm with Pumping crew that they are ready to mix fluids for pumping. 13. Pump a ½” Ball to set lowermost treatment packer. 14. Slack off weight slightly to confirm lower packer is set. 15. Continue to pressure up in 500 psig stages until burst disc pops at ~2,500 psig. Upper packer should set. 16. Begin injecting source water down CT for baseline injectivity. a. Target 800 psig CTP. Document source water injection for 30 minutes. b. DNE 850 psig CT pressure. 17. Contact engineering with injectivity results. This testing is meant to confirm that the MBE has been isolated for pumping the treatment. a. If injection rate is less than 0.5 BPM at 800 psig, consider other pumping options for treatment. 18. Confirm that the Halliburton mixing unit is ready for pumping. 19. Mix 8.7 ppg cross-linked H2Zero product. Note that we have approximately 3 hours to place product prior to setup. a.DNE 770 psig treatment pressure b.Treatment Volumes: i. Source (Fresh) Water Spacer ii. 10 bbls of 8.7 ppg H2Zero injectivity test (straddle packer assembly) run memory tie-in log set upper and lower packers Conformance Treatment Well: MP F-108 iii. Source (Fresh) Water Spacer c. Volume/Gradient Assumptions: i. Coil Capacity: 2” x 0.156” WT = 0.002768 BBL/F ii. Hole Volumes: 1. 34bbls of annular volume back to the swell packer at 7,208’ MD 2. 23.6 bbls of annular volume back to the swell packer at 8,350’ MD 3. 11 bbls of liner volume back to ICD #3 at 7,151’ MD. 4. ~17.3 bbls of Surface Reel Volume with 14,100’ of 2” CT. 20. Place all volume of Crosslinked Gel product into ICD. a. If the treatment screens out early, PU to release packers and dilute H2Zero product by circulating water. Keep pipe moving and circulate a minimum of 21. Displace with 1 bbl of source water into ICD to clear wellbore. 22. POOH. Packers Release at 5500 lb-force. 23. Allow elastomers to relax prior to pulling out of the hole. 24. Flush CT with source water spacer. Attempt to take all returns to tanks to avoid injecting into the well. Wash on way out of hole. 25. POOH to 2,400’ MD and freeze protect well with 36bbls diesel. 26. RD CTU. Allow H2Zero product to setup for 48 hours. 27. Leave injector F-108 Shut in. Slickline 1. RU Slickline. PT PCE to 250 psig Low / 2,500 psig High. 2. Set 4-1/2” MCX injection valve in X-Nipple @ 2,325’ MD. a. Re-run previous MCX injection valve. b. Install 0.50” choke in MCX SSSV. 3. Turn well over to operations to BOL. Function test SSSV. _____________________________________________________________________________________ Revised by: TDF 6/3/2020 SCHEMATIC Milne Point Unit Well: MPU F-108 PTD: 218-021 API: 50-029-23598-00-00 TD =11,961’(MD) / TD =4,107’(TVD) 20” KB Elev above MSL: 37.3’ 4-1/2” 2 9-5/8” 1 3/4 6 See ICD & Swell Packer Detail PBTD =11,955’ (MD) / PBTD =4,107’(TVD) 9-5/8” ‘ES’ Cementer @ 2,294’ MD 4-1/2” 5 CASING DETAIL Size Type Wt/ Grade/ Conn Drift ID Top Btm BPF 20" Conductor N/A / X-52 / Weld N/A Surface 107’ N/A 9-5/8" Surface 40 / L-80 / DWC/C 8.75” Surface 5,658’ 0.0758 4-1/2” Liner 13.5 / L-80 / Hyd 625 3.85” 5,487’ 11,960’ 0.0149 TUBING DETAIL 4-1/2" Tubing 12.6 / L-80 / TXP-SR 3.833” Surf 5,494’ 0.0152 JEWELRY DETAIL No Top MD Item ID Upper Completion 1 2,325’ X Nipple MCX injection valve with .50 bean installed 6/29/18 3.813 2 5,101’ XN Nipple profile: 3.725” No Go / 3.813 Packing Bore 3.725 3 5,482’ 8.25” No-Go Locater on Tieback Assy ([4] - 1” Ported Seal Stem) 3.960 4 5,494’ Tieback Shoe 6.180 Lower Completion 4 5,487’ Liner Top Packer (TVD= 4,081’)- 5 11,955’ WIV (Ball on Seat/ Closed) PBTD - OPEN HOLE / CEMENT DETAIL 42" ~270 ft3 12-1/4"Stg 1 – 370 sx Lead / 400 sx Tail Stg 2 – 267 sx Lead / 264 sx Tail (173 bbl surface returns) 8-1/2” Cementless Injection Liner in 8-1/2” hole WELL INCLINATION DETAIL KOP @ 100’ Max Hole Angle = 93.73° @ 9,791’ MD TREE & WELLHEAD Tree Cameron 4 1/16" 5M w/ 4-1/16” 5M Cameron Wing Wellhead Cameron 11” 5K x sliplock bottom w/ (2) 2-1/16” 5K outs GENERAL WELL INFO API#: 50-029-23598-00-00 Completed by Innovation 4/26/2018 Depth MD Depth TVD ICD/Swell Packer Detail 5,768’ 4,104’Weatherford - ICD w/ 316L mesh, 16 port (3 open / 13 closed) 13.5# bxp 625 Wedge 6,029’ 4,107’Swell Packer – Weatherford Genesis Swell Packer #8 6,581’ 4,117’Weatherford - ICD w/ 316L mesh, 16 port (3 open / 13 closed) 13.5# bxp 625 Wedge 6,882’ 4,111’Swell Packer - Weatherford Genesis Swell Packer #7 7,151’ 4,102’Weatherford - ICD w/ 316L mesh, 16 port (3 open / 13 closed) 13.5# bxp 625 Wedge 7,208’ 4,102’Swell Packer - Weatherford Genesis Swell Packer #6 7,882’ 4,101’Weatherford - ICD w/ 316L mesh, 16 port (3 open / 13 closed) 13.5# bxp 625 Wedge 8,350’ 4,108’Swell Packer - Weatherford Genesis Swell Packer #5 8,655’ 4,118’Weatherford - ICD w/ 316L mesh, 16 port (3 open / 13 closed) 13.5# bxp 625 Wedge 8,999’ 4,124’Swell Packer - Weatherford Genesis Swell Packer #4 9,392’ 4,122’Weatherford - ICD w/ 316L mesh, 16 port (3 open / 13 closed) 13.5# bxp 625 Wedge 9,737’ 4,108’Swell Packer - Weatherford Genesis Swell Packer #3 10,092’ 4,093’Weatherford - ICD w/ 316L mesh, 16 port (3 open / 13 closed) 13.5# bxp 625 Wedge 10,522’ 4,082’Swell Packer - Weatherford Genesis Swell Packer #2 10,878’ 4,077’Weatherford - ICD w/ 316L mesh, 16 port (3 open / 13 closed) 13.5# bxp 625 Wedge 11,263’ 4,088’Swell Packer - Weatherford Genesis Swell Packer #1 11,825’ 4,098’Weatherford - ICD w/ 316L mesh, 16 port (3 open / 13 closed) 13.5# bxp 625 Wedge 7,882’4,101’Weatherford - ICD w/ 316L mesh, 16 port (3 open / 13 closed) 13.5# bxp 625 WICD stuck open ,tit °C1 F- 0 Regg, James B (DOA) Pn ?-1150 From: Sloan Sunderland <ssunderland@hilcorp.com> Sent: Thursday, April 26, 2018 3:46 PM I`eflej Q(F"/ 1e To: Regg, James B (DOA); DOA AOGCC Prudhoe Bay; Brooks, Phoebe L (DOA); Wallace, Chris D (DOA) Cc: Joe Engel; Wyatt Rivard; Monty Myers; William Kruskie Subject: Hilcorp MIT MPU F 108 Attachments: MIT MPU F-1084-25-18.xlsx See attached MIT Form. Thanks Sloan. Sloan Sunderland Hilcorp Drilling Foreman Office- 907-670-3094 Cell- 907-715-0591 Submit to: an repo/malaska.pov: OPERATOR: FIELD I UNIT I PAD: DATE: OPERATOR REP: AOGCC REP: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test AOGCC Insoectors0alaskaCov: oh ebe bmoksalialaska Coy H'Icorp Alaska LLC Milne PonVMPU/Fpatl Sloan Suntletlantl chns Wallaceiltalaska.pov Well MP F-108 INTERVAL Codes Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min, 4=Four Year Cycle F=For PTD 2180210 Type Ink N Tubing 0 0 0 0 0 Type Test P Packer TVD d0R] BBL Pump d ] IA 0 3100 3060 3025 3005 3000 Interval 0 Test psi 1500 -I BBL FEW 4.6 OA 0 0 0 0 0 0 Result P Notes: Pre -Injection MIT -IA on the ng to 3000 psi. Witnessed Waived by Adam Earl. Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type mi Tubing Type Test Packer TVD BBL Pump IA Intervei Test psi BBL Retum OA Result Nates: Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTDTypelnj TubingType Packer TVD BBL Pump IA rvaTest Intel Test psi BBL Return OA Result Notes: Well Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. PTD Type lnl Tubing Type Test BBL Pump IA Interval BBL Retum OA Result I Pressures: Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Type lnj Tubing Type Test BBL PumpIA Intal BBL Return OA Result urea: Welt Pressures: Pretest Initial 15 Min, 30 Min. 45 Min. 60 Min, PTD Type lnj Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Return OA Result otea: Well Pressures: Pretest Ind al 15 Min. 30 Min. 45 Min. 60 Min. PTD Type lnj Tubing Type Test Packer WO BBL Pump IA Interval Test psi BBL Return OA Result Notes: Well Pressures: Pretest molal 15 Min. 30 Min. 45 Min. 60 Min. PTD Typelnl Tubing Type Test Packer TVD BBL Pump IA Interval Test psi BBL Realm OA Rol Notes: TYPE INJ coda" TYPE TEST Codes INTERVAL Codes Result Codes W=We. P=Pressure Tesl 1=1rus, Trut P=Fees G=Gas 0= dher(tleenlbeln N.) 4=Four Year Cycle F=For S - Slurry V= Recalled W Valance 1=lnwnduslve I = Indurod We.., 0 =other leescube In notes) Form 10-426 (Revised 011201]) MIT MPu F.108 4 -2S18