Department of Commerce, Community, and Economic Development
Alaska Oil and Gas Conservation
Commission
HOME
EVENTS
DATA
Data List
Drilling
Production
Orders
Data Miner
Document Search
REPORTS
Reports and Charts
Pool Statistics
FORMS
LINKS
Links
Test Notification
Data Requests
Regulations
Industry Guidance Bulletins
How to Apply
ABOUT US
History
Staff
HELP
Loading...
The URL can be used to link to this page
Your browser does not support the video tag.
Home
My WebLink
About
162-033
STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon LJ Plug Perforations LJ Fracture Stimulate Li Pull Tubing Ll Operations shutdown LJ Performed: Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing Change Approved'Program❑ Plug for Redrill ❑ erforate New Pool ❑ Repair Well ❑ Re-enter Susp Well ❑ Other: CTCO w/N2 ❑✓ 2. Operator Hilcorp Alaska, LLC 4. Well Class Before Work: 5. Permit to Drill Number: Name: Development ❑✓ Stratigraphic❑ Exploratory ❑ Service ❑ 162-033 3. Address: 3800 Centerpoint Dr, Suite 1400 Anchorage, 6. API Number: AK 99503 50--283-10025-00-00 7. Property Designation (Lease Number): 8. Well Name and Number: ADL -0017658 Beluga River Unit (BRU) 212-25 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 1o. Field/Pool(s): N/A Beluga River- Undefined Gas 11. Present Well Condition Summary: Total Depth measured 5,800 feet Plugs measured N/A feet true vertical 5,800 feet Junk measured N/A feet 3256; Effective Depth measured 4,157 feet Packer measured 3389;3883 feet true vertical 4,157 feet true vertical 3256; feet 33789;3883 Casing Length Size MD TVD Burst Collapse Structural Conductor 29' 36" 29' 29' Surface 288' 16" 288' 288' 2,630psi 1,020psi Intermediate 2,364' 10-3/4" 2,364' 2,364' 5,860psi 3,220psi Production 5,776' 7" 5,776' 5,776' 6,340psi 3,830psi Liner Perforation depth Measured depth See Attached Schematic True Vertical depth See Attached Schematic Tubing (size, grade, measured and true vertical depth) 2-3/8" 4.7# / N-80 3,903' MD 3,903' TVD 2 Baker FHL; 3,256' MD/TVD 3,390' MD/TVD Packers and SSSV (type, measured and true vertical depth) Baker Mod D; N/A 3,883' MD/TVD N/A; N/A 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: 0 290 1 10 48 Subsequent to operation: 0 221 1 8 67 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 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 LJ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP ❑ SPLUG ❑ 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 319-287 Authorized Name: Be York 777-8345 Contact Name: Ted Kramer Authorized Title: Operations Manager Contact Email: Akmerloihilcoro.com Authorized Signature: 2 o , �� Date: Contact Phone: 777-8420 Form 10-404 Revised 412017 p #, )4 /oRBDMS. & OC i 0. 2 2019 Submit Original Only Hilcorp Alaska, LLC Well Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date BRU 212-25 CTU #13 50-283-10025-00-00 162-033 7/8/19 1 8/27/19 Daily Operations: 07/08/2019 - Monday Crews arrive at Twin Otter hanger. Travel to Beluga. MIRU SLB CTU 13 with 1.75" CTU. Load Supply tank 300 bbls of produced water. Prep for BOPE in the AM. 07/09/2019 -Tuesday PTW/JSA. Fire equipment. Pick injector head. Stab on well. Start BOPE test. 250/4,000 psi. 24 hr BOPE test witness notification sent 7/8/19 @ 9:50 AM. Witness waived by Jim Regg. No Failures to note. Pop off well and add check valves to BHA. Coil connector, DFCV, Stinger, Jet swirl nozzle. BHA 1.75" OD (SLIM). Stab on well pt stack 250/4,000 psi for 5 minutes. Bleed down. Open well and RIH. Initial WHP 168 psi. RIH not pumping. Dry tag at 3 290' CTMD (sand bridge). Pick up. Online with N2 @ 800 scf/min..4 bbls/min fluid rate. N2 to surface. Start washing. Wash down to XN nipple (1.75" ID) . Tag 3,882' CTMD. Good sand in returns. Returns are slow due to restrictions in well and 1.75" CT. While washing at 3850' noticed less fluid returns to surface. Shut down fluid rate and increase N2 rate to 1000 scf, park at 400'. Lost 38 bbls of fluid into wellbore. RIH from 400' pumping N2 at 450 scf/min. Park at 3,400' and attempt to lift fluid. Mostly N2 at surface. Shut down N2. POOH from 3,400'. Let well flow to open top tank. 132,000 scf pumped forjob. 1420 gallons). At surface. Allow well to flow. 65% LEL on gas monitor. Shut in well. RDMO CTU 13. Well will have to be soaped to get remaining fluid out. CTU rigged down. 08/27/2019 -Tuesday Discussed setting a Plug in the tubing with Reservoir Engineer to shut off water.. Decided not to do so. Close out well. K FlJlsoro Aleeka, LLC RKB to MSL =42' RKB to GL= ©.0=r1lm rd 10-3/4" 3 TOC @ 2,465' 4 5 6 7 8 9 10 it SCHEMATIC Beluga River Unit Well: BRU 212-25 Last Completed: 8/31/1984 PTD: 162-033 API: 50-283-10025-00 rAanrm nrrAu Size Type VVT Grade Conn ID Btm 36" Conductor - 1.875 8rd 32"-34.5" 29' 16" Surface 75# 1-55 S8rd 15.124" 288' 10-3/4" Intermediate 55.5# N-80 5 8rd 9.76" 1,520' 10-3/4" Intermediate 51# N-80 EUE 8rd 9.85" 2,364- 7" Prod Casing 26# P-110 BT R3 6.26" DV's & FC 7" Prod Casing 23# N-80 EUE 8rd 6.366" 5,776- 2-3/8" Heater Strin 4.7# N-80 EUE 8rd 1.995" 2,034' C TUBING DETAILS Min I.D.2-3/8" Productiong String 4.7# N-80 EUE Srd 1.995"3,903' 1 Heater string: 1.75" Production String: 1.75" JEWELRY DETAIL r Prnduntinn cl.inn STRLNG A 6A C 12 D 13/14 15 D PI/P2 a P3 12/62 i 12/62 TMD 5,800' TVD =5,800' PBMD=4,157' PBTVD=4,157' Max Angle =.8 deg @ 986' ID. Depth MD (ft.) ID (in.) V Description 1 16 P2 Tubing Hanger 2 542 1.875 Otix'X' Nipple 3 3,223 - Drilled top 8' of 20sx plug Brown 'CC' Safety Joint 4 3,253 1.875? Otls'SS-XA'Sliding Sleeve 5 3,256 3 Baker FHL ret. Packer, 40k shear, 2.3'to rubbers 6 3,276 Sqz Perf'd Tubing @ 4 spf-open 8/15/92 7 3,295 1.938? 3 Blast Joints 8 3,355 12/23/1962 Brown Safety Joint, straight pull, 60kshear 9 3,365 3,668' Perf'd Tubing @ 4 spf-open 8/15/92 30 3,387 1.875 ? Otis'S5-XA' Sliding Sleeve Open 6/10/1985 it 3,390 3 Baker FHL ret. Packer, 401, shear, 24'to rubbers 12 3,880 1.75 OtIs'XN' Nipple 13 3,881 2.406 Crossover& Locator sub 14 3,883 2.406 Packer & Seals, Baker Model D Permanent 15 3,902 2 Baker Shear out Sub neater HA 573 1.75 Otis'XN' Nipple P1110</Fish ID. Depth MD (ft.) ID (in.) Description Pi 4,069 - Fired Perf Gun, 1-3/8" bullnose, 21'x4 strand wire & 2' wire P2 4,072 - Socket, knuckle joint, sinker, jars, TTL P3 4,152 Partially drilled retainers P4 4,157 - Drilled top 8' of 20sx plug P5 4,270 - Halliburton DM Retainer P6 5,220 - Halliburton drillable retainer W/32sx"A"cmt on top Procne ATinAi nrTArl Sands/Zone Top (MD) Btm (MD) Top (TVD) Btm (TVD) Amt SPF Date Status A 3,338' 3,344' 3,338' 3,344' 6' 4 8/19/1984 Open W50 3,420' 3,421' 3,420' 3,421' - 5 12/13/1962 Sqz A 3,437' 3,458' 3,437' 3,458' - 4 12/23/1962 Sqz C 3,650' 3,668' 3,650' 3,668' - 4 12/23/1962 Sqz WSO 3,732' 3,734' 3,732' 3,734' - 4 12/17/1962 Sqz D 3,815' 3,825' 3,815' 3,825' - 4 8/24/1984 Sqz D 3,866' 3,876' 3,866' 3,875' - 4 8/24/1984 Sqz D 3,901' 3,921' 3,901' 3,921' 20' 4 7/19/1992 Open D 4,008' 4,024' 4,008' 4,024' 16 8 7/19/1992 Open E 4,056' 4,078' 4,056' 4,078' 14 8 7/19/1992 Open E 4,105' 4,111' 4,105' 4,111' 6 4 12/23/1962 Open Created By: JJ 6/16/2016 THE STATE °fALASKA GOVERNOR MIKE DUNLEAVY Bo York Operations Manager Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Beluga River Field, Undefined Gas Pool, BRU 212-25 Permit to Drill Number: 162-033 Sundry Number: 319-287 Dear Mr. York: Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www. a og c c.a laska.g ov Enclosed is the approved application for the 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, tieielowski Commissioner DATED this 17- day of June, 2019. RBDMS w JUN 13 2019 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 CENED JUN 0 7 2019 AOGCt (7 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: CTCO w/ N2 ❑+ -- 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Hilcorp Alaska, LLC Exploratory ❑ Development r Q Stratigraphic ❑ Service ❑ 162-033 3. Address: 3800 Centerpoint Dr, Suite 1400 6. API Number: Anchorage Alaska 99503 50-283-10025-00-00 r 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? N/A Will planned perforations require a spacing exception? Yes ❑ No MBeluga , River Unit (BRU) 212-25 9. Property Designation (Lease Number): 10. Field/Pool(s): ADL0017658 Beluga River - Undefined Gas r 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth ND (ft): Effective Depth MD: Effective Depth ND: MPSP (psi): Plugs (MD): Junk (MD): 5,800' 5,800' 4,157' 4,157'-2,800psi N/A N/A Casing Length Size MD ND Burst Collapse Structural Conductor 29• 36" 29' 29' Surface 288' 16" 288' 288' 2,630psi 1,020psi Intermediate 2,364' 10-3/4" 2,364'2,4' POpsi S,860psi 3,2 Production 5,776' 7" 5,776' 5,7736 66,340psi 3,830psi Liner Perforation Depth MD (ft): Perforation Depth ND (ft): Tubing Size: Tubing Grade: Tubing MD (ft): See Attached Schematic See Attached Schematic 2-3/8" 4.7# / N-80 3,903' Packers and SSSV Type: Packers and SSSV MD (ft) and ND (ft): 2 Baker FHL; Baker Mod D; WA 3,258'MDrrVD; 3,390'MD/TVD; 3,883'MDf VD; N/A, N/A 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: July 15, 2019 OIL ❑ WINJ ❑ WDSPL ❑ Suspended ❑ GAS WAG ❑ GSTOR ❑ SPLUG ❑ 16. Verbal Approval: Date: Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. 1 hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name: Bo York 777-8345 Contact Name: Ted Kramer Authorized Title: Operations Manager Contact Email: tkramernc hilcoro.com Contact Phone: 777-8420 14)\ °I Authorized Signature: Date: COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: vl Ter Plug Integrity ❑ BOP Mechanical Integrity Test ❑ Location Clearance ❑ Other. ,te yV W Post Initial Injection MIT Req'd? Yes ❑ No ❑ RBDMS� JUN 13 2019 Spacing Exception Required? Yes ❑ No Subsequent Form Required: / .- Ll D APPROVED BY Approved by:ell /01,COMMISSIONER THE COMMISSION Date: / -12 _• / Submit Form and 13, Form 10403 evised 4/2017 Approved applicatio s o 2 n fr a date of approval. ttachments in Duplicate 10411/0 � ma 41061 H Hilamp Almke LL Well Prognosis Well: BRU 212-25 Date: 6/5/2019 Well Name: BRU 212-25 API Number: 50-283-10025-00 Current Status: SI Gas Producer Leg: N/A Estimated Start Date: 07/15/2019 Rig: CTU Reg. Approval Req'd? Yes Date Reg. Approval Rec'vd: Regulatory Contact: Donna Ambruz 777-8305 Permit to Drill Number: 162-033 First Call Engineer: Ted Kramer (907) 777-8420 (0) (987) 867-0665 (M) Second Call Engineer: Be York (907) 777-8345 (0) (907) 727-9247 (M) AFE Number: Current Surface Pressure: 60 psi flowing Maximum Expected BHP: —650 psi @ 3,344' TVD (Exp. Res. Press. Sterling A) Max. Predicted Surface Pressure: — 2,800 psi (While pumping N2) Brief Well Summary BRU 212-25 was spudded in November of 1962. The well was originally completed and tested in the E sand in 1962 after testing and squeezing some A and C sands. The well was then SI waiting on surface facilities until October 1984. In 1984, additional Zones were perfed, Tested and Squeezed with the main addition being the A sand. On May 8, 2019 a slick line tag tagged what is believed to be a bridge at 3,306'. This should be in blank pipe. The purpose of this work is to utilize coil tubing and nitrogen to clean out this well to 3,950' and place the well on production. Notes Regarding Wellbore Condition • Fish at bottom of well at 4,069' (pert gun and wire). Coil Tubing Procedure: 1. MIRU Coiled Tubing, PT BOPE to 4,000 psi Hi 250 Low. 2. RU Nitrogen Unit 3. PU wash nozzle and RIH to 3,290' (just above fill tag). 4. Bring on Nitrogen and clean out well to 3,950' through 1-3/4" coil tubing (48' out of the tubing tail). 5. Blow well dry. 6. POOH with Coil. 7. Turn well over to production to test. Attachments: 1. Current Schematic 2. Coil Tubing BOP Stack 3. Current Well Head Diagram 4. CT Flow Diagram Forward Jetting 5. Nitrogen procedure K can Alaska, LLC RKB to Mist. =42' RKB to GL=16.4' 2 10-3/4" TOC @ 2,465' 4 5 6 7 8 9 10 11 12 It Beluga River Unit Well: BRU 212-25 Last Completed: 8/31/1984 SCHEMATIC PTD: 162-033 API: 50-283-10025-00 CASING DETAIL Size Type WT Grade Conn ID Btm 36" Conductor 542 1.875 8rd 32"-34.5" 29' 16" Surface 75# J-55 S8rd 15.124" 288' 10-3/4" Intermediate 55.5# N-80 5 8rd 9.76" 1,520- 10-3/4" Intermediate 51# N-80 ELIE 8rd 9.85" 2,364' 7" Prod Casing 26# P-110 BT R3 6.26" DV's & FC 7" Prod Casing 23# N-80 EUE 8rd 6.366" 5,776- 2-3/8" Heater String 4.7# N-80 EUE 8rd 1.995" 2,034' Tjk ITUBING DETAILS Min I.D. Heater string: 1.75" 2-3/8" Productiong String 4.7# N-80 EUE 8rd 1.995" 3,903' Production String: 1.75" JEWELRY DETAIL Production String STRLNG A A C D 15 D E Pi/P2 P3 I' _ 12/62 TMD =5,800' TVI) =5,800' PBMD=4,157' P8TVD=4,157' Max Angle =.8 deg @ 986' 12/62 ID. Depth MD (ft.) ID (in.) Description 1 16 P2 Tubing Hanger 2 542 1.875 Otix'X' Nipple 3 3,223 - Drilled top 8' of 20sx plug Brown'CC'Safety Joint 4 3,253 1.875 ? Otis'SS-XA' Sliding Sleeve 5 3,256 3 Baker FHL ret. Packer, 401k shear, 2.3'to rubbers 6 3,276 Sqz Perf'd Tubing @ 4 spf-open 8/15/92 7 3,295 1.938? 3Blast Joints 8 1 3,355 1 Brown Safety Joint, straight pull, 60k shear 9 3,365 3,668' Perf'd Tubing @ 4 spf-open 8/15/92 10 3,387 1.875? Otis'SS-XA'Sliding Sleeve Open 6/10/1985 11 3,390 3 Baker FHL ret. Packer, 401k shear, 2.4'to rubbers 12 3,880 1.75 Otis'XN' Nipple 13 3,881 2.406 Crossover& Locator Sub 14 3,883 2.406 Packer & Seals, Baker Model D Permanent 15 3,902 2 Baker Shear out Sub Heater HA 573 1.75 1 Otis'XN' Nipple Plues/Fish ID. Depth MD (ft.) ID (in.) Description Pi 4,069 - Fired Perf Gun, 1-3/8" bullnose, 21'x4 strand wire & 2' wire P2 4,072 - Socket, knucklejoint, sinker, jars, TTL P3 4,152 - Partially drilled retainers P4 4,157 - Drilled top 8' of 20sx plug PS 4,270 - Halliburton DM Retainer P6 5,220 - Halliburton drillable retainer w/ 32sx "A" cmt on top PERFORATION DETAIL Sands/Zone Top (MD) Btm (MD) Top (TVD) Btm (TVD) Amt SPF Date Status A 3,338' 3,344' 3,338' 3,344' 6' 4 8/19/1984 Open WSO 3,420' 3,421' 3,420' 3,421' - 5 12/13/1962 Sqz A 3,437' 3,458' 3,437' 3,458' 4 12/23/1962 Sqz C 3,650' 3,668' 3,650' 3,668' - 4 12/23/1962 Sqz WSO 3,732' 3,734' 3,732' 3,734' 4 12/17/1962 Sqz D 3,815' 3,825' 3,815' 3,825' - 4 8/24/1984 Sqz D 3,866' 3,876' 3,866' 3,875' - 4 8/24/1984 Sqz D 3,901' 3,921' 3,901 1 3,921' 20' 4 7/19/1992 Open D 4,008 ' 4,024' 4,008' 4,024' 16 8 7/19/1992 Open E 4,056' 4,078' 4,056' 4,078' 14 8 1 7/19/1992 Open E 4,105' 4,111' 1 4,105' 4,111' 6 4 1 12/23/1962 Open Created By:A 6/16/2016 K II'l—,t, %I 'A., LU 2" 1502 Flan 0 2 -vv 10K Coil Tubing BOP Coiled Tubing HR580 Injector Head & Gooseneck Weight = 12,850 lbs 4-1116" 10K Conventional Stripper SK 0062 Lubricator 5K C062 x 4-1116" 10K Flange 4.1116" 10K Combi BOP Top Set BlIna/Shear Sewntl Set Pope/Sie 4-1116" 1 O Flow Cross Manu& 2x2 Valve i'. 2" 1502 x 2-1/16" 10K Ratge M-tA 2x2 Valve2: 2-1/16" 10K x2-1/16" tOK Flarge Manual 2x2 Valve 3 2-1/16" 10K x2-1116" 10K Flange Manus 2x2 Valve 4' 2" 1502 x 2-1116" 10K flange 4-1116" 1 O x Wellhead Adapter Flange Wellhead Beluga River BRU 212-25 Current 06/06/2019 Beluga River Unit Tubing hanger, Shaffer, BRU 212-25 T-59AD, 7 X 2 3/8 EUE lift 16x 10%x]. 23/8x23/8 and susp%23/B EUE Iift and susp w/ 2" Cosasco back pressure valve preps, 3 35/64 centers Tubing head, Shy T- 59D L1, 1151 71/16 SM, w/ 2- 2 1 S50 Casing spool, Shaffe 16 3/4" 3M x 115M, 21/16 SM 550 Starting head, Shaffer I 16 3/4" 3M x 16" Casi thread, w/ 2- 2 1/16 LI 21/15 5M x 21/16 SM Dual segmented tree assy 23/81, Open—Top Tank w/ Diffuser up Annulus) COILED TUBING UNIT N2 JETTING ROW SCHEMATIC STANDARD WELL PROCEDURE ❑flcorp Alaska, LIX NITROGEN OPERATIONS 1.) MIRU Nitrogen Pumping Unit and Liquid Nitrogen Transport. 2.) Notify Pad Operator of upcoming Nitrogen operations. 3.) Perform Pre -job Safety Meeting. Review Nitrogen vendor standard operating procedures and appropriate Safety Data Sheets (formerly MSDS). 4.) Document hazards and mitigation measures and confirm flow paths. Include review on asphyxiation caused by nitrogen displacing oxygen. Mitigation measures include appropriate routing of flowlines, adequate venting and atmospheric monitoring. 5.) Spot Pumping Unit and Transport. Confirm liquid N2 volumes in transport. 6.) Rig up lines from the Nitrogen Pumping Unit to the well and returns tank. Secure lines with whip checks. 7.) Place signs and placards warning of high pressure and nitrogen operations at areas where Nitrogen may accumulate or be released. 8.) Place pressure gauges downstream of liquid and nitrogen pumps to adequately measure tubing and casing pressures. 9.) Place pressure gauges upstream and downstream of any check valves. 10.) Wellsite Manager shall walk down valve alignments and ensure valve position is correct. 11.) Ensure portable 4 -gas detection equipment is onsite, calibrated, and bump tested properly to detect LEL/H2S/CO2/O2 levels. Ensure Nitrogen vendor has a working and calibrated detector as well that measures 02 levels. 12.) Pressure test lines upstream of well to approved sundry pressure or MPSP (Maximum Potential Surface Pressure), whichever is higher. Test lines downstream of well (from well to returns tank) to 1,500 psi. Perform visual inspection for any leaks. 13.) Bleed off test pressure and prepare for pumping nitrogen. 14.) Pump nitrogen at desired rate, monitoring rate (SCFM) and pressure (PSI). All nitrogen returns are to be routed to the returns tank. 15.) When final nitrogen volume has been achieved, isolate well from Nitrogen Pumping Unit and bleed down lines between well and Nitrogen Pumping Unit. 16.) Once you have confirmed lines are bled down, no trapped pressure exists, and no nitrogen has accumulated begin rig down of lines from the Nitrogen Pumping Unit. 17.) Finalize job log and discuss operations with Wellsite Manager. Document any lessons learned and confirm final rates/pressure/volumes of the job and remaining nitrogen in the transport. 18.) RDMO Nitrogen Pumping Unit and Liquid Nitrogen Transport. 12/08/2015 FINAL vl Page 1 of 1 DEPT. OF ENVIRONMENTAL CONSERVATION DIVISION OF ENVIRONMENTAL HEALTH SOLID WASTE PROGRAM 410 W1LLOUGltBY AVE., SUITE 303 JUNEAU, ALASKA 99801 http://www.state.ak.us/dec/deh September 14, 2001 Telephone: (907) 465-5162 Fax: (907) 465-5362 Ms. Lisa Pekich Senior Environmental Coordinator Phillips Alaska, Inc. P.O. Box 100360 Anchorage, AK 99510-0360 Reference: Issuance of Permanent Closure Approval for Inactive Reserve Pits located at nine exploration sites located on the North Slope, SouthCentral, and Interior Alaska Dear Ms. Pekich: The Alaska Department of Environmental Conservation (ADEC) has completed review and public notice for nine inactive reserve pit closure applications and requests for permanent closure approval. The closure applications provided the required information describing the history of the reserve pit(s), the present condition of the reserve pits(s), results of any required water sampling and an assessment of the potential risks posed by the drilling waste to human health and the environment. At these locations, the reserve pits have been backfilled and there is no exposed drilling waste. ADEC coordinated review of the closure requests with the appropriate land manager(s). Public notice requesting comments on the closure requests was published August 3 and 4, 2001 in the Anchorage Daily News and posted on the State Web Site August 2, 2001.. No public comments were received in response to this public notice. ADEC has determined that the reserve pits at these sites meet the closure re. quirements of 18 AAC 60.440. Closure Approval Under authority of 18 AAC 60.440 (j), ADEC grants permanent closure approval to Phillips Alaska 'inc. for the inactive reserve pits at the following nine exploration sites: Well Name API Number Beluga River Unit 212-25 ! Q~ 50'283-10025-00 Birch Hill Unit 22-25 ~,a~,~ 50-133-10029-00 Swan.Lake Unit # 2 p~lX 50-133-10021-00 /aC)t4.55Falls Creek Unit # 1 (13-06) ,.,,~,t,50-133-10005-00 Rainbow Federal # 1 9~ 1'~ 50-099-10004-00 Rainbow Federal # 2 ? ~ I~, 50-099-10005-00 I t,~-~%oKaliakh #2t2 RD ~'~' I~ 50-033-10002-00/01 KRU West Sak SWPT #15o59 50-029-20915-00 West Sak River State # 2 '~'~"~'b 50-029-20134-00 MTRS Sec. 25 13N, 10W,SM Sec. 25 09N, 09W,SM Sec. 3 07N, 006W,$M Sec. 6 01N, 12W,SM Sec. 31 08N, 05W,CR Sec. I 08N, 05W,CR Sec. 28 20S, 014E,CR · Sec. 11 IlN, 10E,UM Sec. 22 11N,10E,UM Landowner ADNRJADF&G US~S US~S %x ~v Private Property BLM /k~"lf,_O ( 99C,=, e,.~ pnnted on recycteO oape~ Phillips Alaska, Inc. Ms. Lisa L. Pekich September 14, 2001 Page 2 Terms and Conditions This final closure approval is subject to the following terms and conditions: 2) In accordance with 18 AAC 60.440(1), the Depar~ment will require additional investigation, assessment, monitoring or remediation if new information regarding conditions at the reserve pit facilities indicates that further actions are necessary to protect human health or the environment. The approval granted by this letter is for the inactive drilling waste reserve pit(s) only. Closure for the pad as a whole (if required) must be coordinated between the owner/operator and the appropriate land owner/manager. Any person who disagrees with any portion of this decision may requeSt an adjudicatory hearing in accordance with 18 AAC 15.200-310. The request should be mailed to the Commissioner of the Department of Environmental Conservation, 555 Cordova Ave. Anchorage, AK 99501. If a hearing is not requested within thirty (30) days of the date of this letter, the right of appeal is waived. If an adjudicatory hearing is requested and granted, this decision remains in full effect during the adjudicatory process. Sincerely, Heather T. Stockard Solid Waste Program Manager Heather Stockard @envircon.state.ak. us CC: Harry Bader, ADNR, 3700 Airport Way, Fairbanks, AK 99709-4699 Deborah Heebner, ADNR, 550 W 7th Ave. Suite 900C, Anchorage, AK 99501-3577 William Friar, BP Exploration, P.O. Box 196612, Anchorage, AK 99519-6612 Don McKay, ADF&G, 333 Raspberry Rd., Anchorage, AK 99502 Harold Pederson, 925 R Street, Anchorage, AK 99501 BLM, Ramone McCoy, BLM District Manager, Box 147, Glennallen, AK 99588 Claire Caldes, USFWS, Box 2139, Soldotna, AK 99669-2139 Charles Underwood, Marathon Oil Company, P.O. Box 196168, Anchorage, AK 99519-6168 ALASKA OIL AND GAS CONSERVATION COMMISSION WALTER J. HICKEL, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 TELECOPY: (907) 276-7542 July 26, 1994 Mark H Wittow Preston Gates & Ellis 420 L St Ste 400 Anchorage, AK 99501-1937 Re: Z-Energy Spacing Exception Request Dear Mr Wittow: In the course of its deliberations in the above-referenced matter, the Commission has found it helpful to refer to its public files of well records and production records relating to the Beluga River field and surrounding areas. This letter is to ensure that you are aware that the Commission takes official notice of the contents of these public well files: Beluga River Unit 212-35 Beluga River Unit 214-35 Beluga River Unit 212.25 ~...~ '-O ~ '~ ~ ~' Beluga River Unit 232-09 Beluga River Unit 232-04 Beluga River Unit 224-23 Beluga River Unit 233-27 Beluga River Unit 232-26 Beluga River Unit 14-19 Beluga River Unit BRWD-1 Beluga River Unit 244-04 Beluga River Unit 211-03 Beluga River Unit 212-24 Beluga River Unit 224-34 Beluga River Unit 241-34 Beluga River Unit 214-26 Beluga River Unit 224-13 Burglin X33-12 Beluga River Unit 212-18 Pretty Creek Unit #1 Beluga River Unit 221-23 Data specifically referenced in the files included open hole well logs, completion information, including perforation intervals and production data. If you wish to rebut any of the material in these files, please notify the Commission no later than August 8, 1994. Such notification should include a statement of whether you wish to submit a rebuttal in writing or at an oral hearing and, if the latter, the reasons you believe a written submission would be insufficient. . .. Chairman ~ ~ WALTER J. HIGKEL, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 TELECOPY: (907) 276-7542 July 26, 1994 D A Grove, BRU/Kup Staff Mgr ARCO Alaska Inc P O Box 100360 Anchorage, AK 99510-0360 Re: Z-Energy Spacing Exception Request Dear Ms Grove: In the course of its deliberations in the above-referenced matter, the Commission has found it helpful to refer to its public files of well records and production records relating to the Beluga River field and surrounding areas. This letter is to ensure that you are aware that the Commission takes official notice of the contents of these public well files: Beluga River Unit 212-35 Beluga River Unit 214-35 Beluga River Unit 212-25 Beluga River Unit 232-09 Beluga River Unit 232-04 Beluga River Unit 224-23 Beluga River Unit 233-27 Beluga River Unit 232-26 Beluga River Unit 14-19 Beluga River Unit BRWD-1 Beluga River Unit 244-04 Beluga River Unit 211-03 Beluga River Unit 212-24 Beluga River Unit 224-34 Beluga River Unit 241-34 Beluga River Unit 214-26 Beluga River Unit 224-13 Burglin X33-12 Beluga River Unit 212-18 Pretty Creek Unit #1 Beluga River Unit 221-23 Data specifically referenced in the files included open hole well logs, completion information, including perforation intervals and production data. If you wish to rebut any of the material in these files, please notify the Commission no later than August 8, 1994. Such notification should include a statement of whether you wish to submit a rebuttal in writing or at an oral hearing and, if the latter, the reasons you believe a written submission would be insufficient. David W Joh[~Ston Chairman jo/rpc~z-energy ~.~) Drinted on recycled p~per !.~ ¥' C. ~ ALASKA OIL AND GAS CONSERVATION COMMISSION WALTER J, HIGKEL, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 TELECOPY: (907) 276-7542 July 26, 1994 Rosanne M Jacobsen, ^tty ARCO Alaska Inc P O Box 100360 Anchorage, AK 99510-0360 Re: Z-Energy Spacing Exception Request Dear Ms Jacobsen: In the course of its deliberations in the above-referenced matter, the Commission has found it helpful to refer to its public files of well records and production records relating to the Beluga River field and surrounding areas. This letter is to ensure that you are aware that the Commission takes official notice of the contents of these public well files: Beluga River Unit 212-35 Beluga River Unit 214-35 Beluga River Unit 212-25 Beluga River Unit 232-09 Beluga River Unit 232-04 Beluga River Unit 224-23 Beluga River Unit 233-27 Beluga River Unit 232-26 Beluga RiverUnit 14-19 Beluga RiverUnit BRWD-1 Beluga River Unit 244-04 Beluga River Unit 211-03 Beluga River Unit 212-24 Beluga River Unit 224-34 Beluga River Unit 241-34 Beluga River Unit 214-26 Beluga River Unit 224-13 Burglin X33-12 Beluga River Unit 212-18 Pretty Creek Unit #1 Beluga River Unit' 221-23 Data specifically referenced in the files included open hole well logs, completion information, including perforation intervals and production data. If you wish to rebut any of the material in these files, please notify the Commission no later than August 8, 1994. Such notification should include a statement of whether you wish to submit a rebuttal in writing or at an oral hearing and, if the latter, the reasons you believe a written submission would be insufficient. Chairman jo/rpc~z-energy r~,~ printed on recycled paper ALASKA OIL AND GAS · CONSERVATION COMMISSION WALTER J, HICKEL, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 TELECOPY: (907) 276-7542 July 26, 1994 Paul Craig, President Z-Energy Inc 2900 Boniface Pkwy #610 Anchorage, AK 99504-3132 Re: Z-Energy Spacing Exception Request Dear Mr Craig: In the course of its deliberations in the above-referenced matter, the Commission has found it helpful to refer to its public files of well records and production records relating to the Beluga River field and surrounding areas. This letter is to ensure that you are aware that the Commission takes official notice of the contents of these public well files: Beluga River Unit 212-35 Beluga River Unit 214-35 Beluga River Unit 212-25 Beluga River Unit 232-09 Beluga River Unit 232-04 Beluga River Unit 224-23 Beluga River Unit 233-27 Beluga River Unit 232-26 Beluga River Unit 14-19 Beluga River Unit BRWD-1 Beluga River Unit 244-04 Beluga River Unit 211-03 Beluga River Unit 212-24 Beluga River Unit 224-34 Beluga River Unit 241-34 Beluga River Unit 214-26 Beluga River Unit 224-13 Burglin X33-12 Beluga River Unit 212-18 Pretty Creek Unit #1 Beluga River Unit 221-23 Data specifically referenced in the files included open h01e well logs, completion information, including perforation intervals and production data. If you wish to rebut any of the matedal in these files, please notify the Commission no later than August 8, 1994. Such notification should include a statement of whether you wish to submit a rebuttal in writing or at an oral headng and, if the latter, the reasons you believe a written submission .~. David W Johnston \ Chairman ~.~ jo/rpc~z-energy ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 August 24, 1992 Commissioner Leigh Griffin Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Subject: Report of Sundry Well Operations for BRU 212-25 Perforation. Dear Commissioner Griffin: On July 17, 1992 ARCO Alaska Inc. successfully completed the perforation of the D & E zones from 3904' to 4062' on BRU 212-25. EnclOsed are the Report of Sundry Well Operations, a Well Service Report, and a well schematic for reference. If you need additional information, please call Brian Noel at 263-4879. Sincerely, J. C. Winn Acting Regional Engineer JCW:JLB:0177 Attachment CC: Mr. M. R. Williams Mr. Mike W. Sellers Shell Western E&P, Inc. Chevron USA, Inc. ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany Naska 0it 8, Gas Cons. C0m~ssi°~ Anchorage STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS !1. Type of Request: Operation Shutdown m Stimulate __ Plugging Perforate Pull tubing Alter casing Repair well Pull tubing Other 2. Name of Operator ARCO Alaska. 3. Address P. O. Box 100360, Anchorage, AK 99510 4. Location of well at surface 5. Type of Well: Development Exploratory Stratigraphic Service 2015' S & 595' E of NW Corner, Sec. 25, T13N, R9W, SM At top of productive interval At effective depth At total depth Straight Hole 12, Present well condition summary Total Depth: measured true vertical 5800' feet 5800' feet Plugs (measured) 6. Datum elevation (DF or KB) 42' KB. GL 27' feet 7. Unit or Property name Beluga River Unit 8. Well number BRU 212-25 9. Pe it n r/approval I10. APl number 50-283-10025-00 11. Field/Pool Beluga river/Beluga-Sterling number Effective depth: measured 41 5 7' feet true vertical 4157' feet Junk (measured) Casing Length Size Cemented Structural Conductor 29' 3 0" D rive n Surface 2 8 8' 1 6" yes Intermediate 2364' 1 0-3/4" yes Production 577 6' 7" yes Liner Measureddepth Trueverticaldepth 29' 29' 288' 288' 2364' 2364' 5776' 5776' Perforation depth: measured Current: See attached Well Schematic true vertical Current: See attached Well Schematic Tubing (size, grade, and measured depth) 2-3/8" 4.7# N80 @ 3903' Packers and SSSV (type and measured depth) Packers: Baker FHL @ 3263' & 3397'~ Baker mod. D @ 3887' 13. Stimulation or cement squeeze summary Intervals treated (measured) Proposed: See attached Well Re-perf procedure Proposed: See attached Well Re-perf procedure Treatment description including volumes used and final pressure N/A RECEIVED A U6 2 ? 199 Alaska Oil & Bas Cons. Commission Anchorage Reoresentative Daily Average Productioq or In!ection Data OiI-Bbl Gas-Md Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 2O79 100 1110 Subsequent to operation 21 41 I 1 0 I 1 00 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: Oil m Gas X Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge, Signed ~~ 'L~__~/~ ~ ~ Title Cook Inlet Recjional Encjineor Form 10-404 Rev 06/15/88 Date ~I~.~//~ ~- SUBMIT IN DUPLICATE ARCO Alaska, Inc. BRU 212-25 Spud Date: 11/62 Last Compl: 8/84 Schematic Rev: 8/14/92 ~E I/4NW 1/4 Sec.25,T13N,R10W,SM Belu.q. fiver Unit =_j,.. API . 283-1002500 Original RKB (Depth EeO: Ground Level: Maximum Hole Angle: Angle at Perforations: Jewelry 1 16.40' 2 542' 1.17' 3 3223" 1.41' 4 3253' 2.85' 5 3256' 7.30' 6 3294" 60.11' 7 3355' 2.45' 8 3386' 3.05' 9 3389' 7.65' 10 3881' 1.30' 11 1.09' 12 3887' 4.05' 13 3891' 14.96' 14 3903' .67' 15 4157' A 573' 1.28' B 2034' Casing and Tubing Well Type: Gas Producer 42 Annulus Fluid: Diesel 27' Top of Sterling: 332[7 < 1 ° ASP: 2628328,323854 < 1° Single w/heater string R'£ £1VED Tubing Hanger Ofls"X' Nipple, AUG ~ 7 19~ 1.875" Brown CC Safef~t~ka Oil ~. ,~- - ~' otis *XA' Sliding Sleeve ' ~a? Cons. C0rnrnissin,, . Baker FHL Ret. Pkr. 40M# ~orage . 3.00 3 Blast Jts. 3296'-3356' Brown Safety Jt. Straight pull 60M~shear Offs "XA" S S (open 6/10/8,~) Baker FHL Ret. Pkr. 781-36 DM 3.00" Otis "×N" Nipple(Plua set 7129192) 1.75" Tubing Locator Sub 2.406" Baker Model "D" Perm Pkr. 3.250" Seals Model "D" Extended Bore Pkr. 2.406" Baker Shear Out Sub 2.00" Top of Plug Offs" XN" Nipple Heater Srlng Tubing Tall ~ Size Weight Grade ~ To~ Bottom Conductor 36" 16.4' 29' Surface 16" 75f J-55 8RD 16.4' 288' Intermediate 10 3/4" 55.5#/51# N-80 8RD 16.4' 2364' Production Csg 7" 23~/26~ N-80/P110 8RD 16.4' 5776' Pruducffon 11:)g 2 3/8"(1) 4.7# N-80 EUE-8RD 16.4' 3903' Heater 2 3/8"(2) 4.7# N-80 EUE-8RD 16.4" 2034' 2.375" 2.375" 6.078" 3" 2.375" 6.078" 2.375" 3'.437" 5.687" 3.234" 2.875" 2.375" 12 TD '5800' Perforations Net Zone MD Density E.~ Interval Status A 3338'-3344' 4 ~' p~ck~r O~3en 6/85 3420' /' 5 SQZ. Closed 3437'-3458' ~' 4 SQ7... Closed C 3650'-3668' j 4 SQ7.. Closed 3732'-3734' -/ 4 SQT... Closed D 3815'-3825' 4 SQZ Closed 3866'-3875' 4 SQZ Packer Closed 3901 '-3921'/ 8 20' Closed 7/92 4008'-4014"/' 16 6' Closed 7/92 4014'-4020" ~- 8 6" Closed 7/92 4020'-4024' /~-- 12 4" Closed 7/92 E 4056'-4060' 12 4' Closed 7/92 4068'-4078'~ 4 10' Closed 7/92 4105'-4111' ~' ~1 4 6' Closed 7/92 Fish #1 sinker bar-5', knuckle Joint & rope socket-14') Rsh~2: 4-21" strands pert gun wire w/bullnose, 1-2' stra nd 7/19/92 : Siickline tools (17' 2"-1.5"OD) 6/22/92 (TTL-I', spang Jars-6', open hydraulic Jars-4', fluid & sand at 4104' RKB X nipple at 3880', no fill PX plug at 3881' RKB, no fill fill at 4013' RKB fill at 4090' RKB sand slum/3500', fill 3839' WLM 1/25/85 Sinker bar 9/6/85 1.75" gauge ring 5/4/91 1.8" gauge ring 5/3/92 1.75" bailer 6/22/92 1.75" bailer 8/11/92 1.75" bailer JLB 8/14/92 JUL-~-l-1992 13: 59 FROM RIVER J~DT TO N~u UENTU~E P. e~ WE:l.i. ~m"HVll3~ REPORT DI:,EFUiYION AT REPORT TIME o'~,D~ &,.~ ~ Jo~5 m RECEiVeD · ] CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK Vel. knots { $1gngd _ UENTURE P 01 ..,.,..,. ,ar:nvl~ HEPOF =~UL-?.£-19~2 13: 5B FROM pm~ RIVER TO ~-~I NEW ' V~i.L.. ' I" '~o'r : ' i F~.n- om'm~cr'-s--'r~ -' : ~ ~ iotas i o~ ~ ~ ~.~e- ~ _ ,~~ z' .._,._ , . . _ : .. . . .. t~ '_.~~*', ~ . ~ ~ - ....... . :~M ~ , . _ . .... - ..... ..... . ._ ' : ~ , _-- ~ ~ ,.>- ~ ~ ~ - . ..... ._- .~v~ ..-~---_ --,,-- , [ -- · 1~ Al~ ~ ~a~f'~o ~o~ ~'4~' .... _ ',. - " ' -- - -- ¢ - . ' ~ ~ ..... 4 Ir ~'~ -~, '~ ~ J' : ~ ~ - i m t ii t ..... } ~' , ..... , · ._,_ . _~-: .......... 1~%~ ' ' ' ' ' ~ ' CHECK ~18 BLOCK IF SUMMARY CON~NUED ON BACK ' ' ~ ~ : ~ JUL;2t-',i992 1~:58 MI=MARKS CONTINUED:. FROM ~..=.x~,GA RIVER TO .~, I NEW VENTURE,., P. 02 .m i ~ml i . j . 4070' ~ ~ (l[~5 . ~00~ _.l~;~ t~. .., ,, ~- ~ ) ..... . J Il I I % r l ,'~ ........... ,. ~ ' I I A~3CUM' DESCRIPTION DAILY ' , ,, t TOTAL cAMcO I Il ~ ~1 Ill i i , i Ill mlm I I i Ill OTIS SCHLUMBERGER , I [ DOWELL 1 HAILLiB, URTbN ................ ~ ~OTl~ ~01~ ~IN~ ........... ~~~ ........... , I I I B, ~J! HU~H~ ........... Rousta~uts -- Il I " I I lmm I mi Diesel I II I I I iiI I Methanol i i i i i lllll , , ii i ........ .... i m~ I~ ~ i I I ....... i IIII i i l ~ - , mill I I " ' I B0muu~ i i i i il i .' i ARCO Alaska, Inc. Post Office Box '~00360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 Cook Inlet Engineering July 7, 1992 Mr. L. Smith Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Subject: Submittal of Application for Sundry Approval for BRU 212-25 reperforation. Dear Mr. Smith: Attached is an Application for Sundry Approval for a reperforation of the Sterling and Beluga zones from 3903'-4080' on BRU 212-25. Please refer to the attached perforating procedure and well schematic for details of this operation. If you require any further information in this regard, please call Brian Noel at 263-4879. Sincerely, J.C. Winn Acting Regional Engineer JCW:DRH:jlg:0159 RECEIVED J U L - 8 1992 Alas~ 0il & Gas Cons. Commission nch0rage Attachment CC: Mr. C. Kidwell Mr. D. San ti Shell Western E&P, Inc. Chevron U.S.A., Inc. ARCO Alaska, Inc. is a Subsidiary of Atlantic Richfield Company STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon _ Suspend Alter casing _ Repair well Change approved program_ Operation Shutdown_ Re-enter suspended well_ Plugging _ Time extension _ Stimulate __ Pull tubing _ Variance _ Perforate ~( Other 2. Name of Operator ARCO Al?tska, Inq, 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development Exploratory Stratigraphic Service 4. Location of well at surface 2015' S & 595' E of NW Corner Sec. 25, T13N, Rgw, SM At top of productive interval At effective depth At total depth Strai~/ht Hole 12. Present well condition summary Total Depth: measured 5800' true vertical 5800' Effective depth: measured 4157' true vertical 41 57' Casing Length Size Structural Conductor 2 9' 3 0" Surface 288' 1 6" Intermediate 2364' 1 0-3/4" Production 57 76' 7" Liner Perforation depth: measured Current: See Attached Well Schematic true vertical Current: See Attached Well Schematic Tubing (size, grade, and measured depth 2-3/8" 4.7# N80 @ 3903' Packers and SSSV (type and measured depth) feet Plugs (measured) feet feet Junk (measured) feet Cemented Driven yes yes yes 6. Datum elevation (DF or KB) 42' KB. GL 27' feet 7. Unit or Property name Beluga River Unit 8. Well number BRU 212-25 9. Permit number 10. APl number 50-283-10025-00 11. Field/Pool Belugit~ d U L - 8 1992 Alas~ 0il & Gas C0~s. Measured d*p~~"iml d~pth 29' 29' 288' 288' 2364' 2364' 5776' 5776' Proposed: See Attached Well Proposed: See Attached Well Packers: Baker FHL @3263' & 3397', Baker mod. D @ 3887' 13. Attachments Description summary of proposal X Detailed operation program Re-perf procedure Re-perf procedure BOP sketch X 14. Estimated date for commencing operation July, 1992 16. If proposal was verbally approved Name of approver Date approved 15. Status of well classification as: Oil ~ Gas ~( Service Suspended J17. I he~..~..~ertify that the foregoing is true and correct to the best of my knowledge. Title Actin9 Re~iional Engineer. FOR COMMISSION USE ONLY Date '?/7/'~ Z-. Conditions of approval' Plug integrity B Mechanical Integrity Test Notify Commission so representative may witness IApproval~N~/. BOP Test _ Location clearance__ -~,pproved! ~npy~"/, '~ / ~/ _ Subsequent form require 10-~/'0~ Returned '7- I _ Original Signed By David W. Johnston Commissioner Date ? l/I~ / ~ ~ SUBMIT IN TRIPLICATE Approved by the order of the Commission Form 10-403 Rev 5/03/89 OBJECTIVE: WELL BRU 212-25 Re-perforating Procedure BR 23 June 23, 1992 RECEIVED Alaska Oil & Gas Cons. Commission Anchorage. Re-perforate the Beluga D and E intervals to control sand production. Since pulling the tubing plug, attempts to test the well and determine an incremental rate for the Beluga D and E, have been unsuccessful due to sand production. Slickline tags after short periods of flow testing indicate that sand has been unloaded from inside the casing, uncovering most of the perforated interval. Increasing perforation density at 180° phasing is proposed to allow radial flow with decreased velocity into the casing in an attempt to halt sand production. The ability to produce the Beluga zones may add an estimated 2 MMSCFPD to the well's proven deliverability of 2.2 MMSCFPD from the Sterling A. WELL STATUS: BRU 212-25 is currently shut in due to sand production. Prior to pulling tubing plug, the well was producing 2.2 MMSCFPD from the Sterling Slickline tools were left in the well while locating the tubing tail. Last Tag Fill: 4090' MD - 6/22/92 with 1.75" bailer. Plug: Pulled tubing plug from 3881' MD on 5/3/92. FISH: (17' 2" TTL and jars) at 4073' MD on 6/22/92, sketch attached. the A. Pressures: SITP 1400 psi Reservoir Pressure: 1268 psi @ -3300 MD (4/91 - Sterling A) 1620 psi @ -3915 MD (8/84 - Beluga D/E) Tubing size: 2-3/8" Casing size: 7" (gas filled, no fluid level detected) Min. ID: 1.875" (2-3/8 .... X" nipple @ 3881' MD) PERFORATION DATA; Tie-in Log: 08/23/84 Schlumberger CET (5"). CET is off depth with DIL (CET = DIL+2'). DIL: 11/19/62 Schlumberger (5") CNL: 08/08/84 CNL (5" cased hole neutron) may be used for collar identification, but porosity, repeat and neutron sections are off depth with each other and the DIL. Run No. ZONE 1' E 2 E 3 D 4+ D Interval (MD-CET) Interval (MD-DILl ~ SPF 4070-4080 4068-4078 1 0* 4 4058-4062 4056-4060 4 4 401 0-4024 4008-4022 1 4 4 3903-3923 3901-3921 20+ 4 48 NOTES: Gamma Ray will be run to tie-in to DIL curve. All intervals to be shot twice with 1 11/16" formed wire guns and 180° phasing. Decentralizing magnet's orientation at 0° for first run and 90° for second run. *Shooting interval contingent upon GR tie-in and calculation of fish location. +Adjust interval to allow minimum of 2' between top shot and tubing tail. PROCEDURE: Before beginning operations hold a safety meeting with all personnel involved and obtain a detail diagram of all tools to be run in the well. 1. Note SITP and record on WSR. Well is to remain shut in during perforating operations. 2. Rig-up electric line unit and lubricator. . Make-up tool string of adequate weight bars, CCL and GR for tie-in run (determine tubing tail location with respect to CET and DIL by logging at least to above 'X' nipple @ 3881' MD). 4. Pressure test lubricator to 2500 psi per wireline supervisor's instructions. Tapping diesel heat string supply line may be used to fill the lubricator. . RIH, complete CCL/GR correlation log, POOH. Determine location of slickline fish and if any of Run #1 can be safely shot. . Make-up tool string of adequate weight bars, perforating guns, decentralizer and CCL. Turn off radios, phones and electric welders before arming perforating guns (4 SPF with 180° phasing and 0° orientation of magnet - shoot across low side of casing). Once tool string, is running into well, equipment may be returned to service at the discretion of the wireline supervisor. 7. RIH with well shut-in at wing valve and tie in with CET log (depths in bold print). 8. Park gun at proper depth and fire. 9. POOH and tum off radios, phones and electric welders before reaching the surface. Check gun and record depths of any misfires. Repeat the gun run if necessary. 10. Check for any change in SITP following each run. 11. Make up next gun to re-shoot interval. Repeat steps 6 through 11 listed above, ag. ain loading guns at 4 SPF with 180° phasing, but use 90° orientation of magnet - shoot across casing. 12. Upon completion of both runs for first interval, repeat steps 6 through 11, for the remaining 3 runs (shooting each interval twice). 13. Rig down electric line unit and lubricator. 14. Return well to production, bring on slowly and monitor for associated sand and/or water. JUL - 8 1992 Alaska Oil & Gas Cons. Commission Anchorage ARCO Alaska, Inc. t BRU 212'25 .j Spuci Date: 11/62 J Last Compt." . 8/84 Belucja River Unit Schematic Rev: 9/17/91 SE I/4Nw 1/4 Sec.25,T13N,R10W,SM L. API~. 283-10025-00 Original RKB (Dept~ ReO: Ground Level: Maximum Hole Angle: Angle at Perforations: Jewelrlf 1 16.40' 2 542' 1.17' 3 3223' 1.41' 4 3256' 2.85" 5 3263' 7.30' 6 3302" 60.11' 7 3357' 2.45" 8 3389' 2.85' 9 3397' 7.65' 10 3881' 1.30' 11 1.09' 12 3887' 4.05' 13 3891' 14.96' 14 3903' .67' 15 4157' A 573* 1.28' B 2034' 42 27' <1' <1' Well Type: Ga~ Proaucer j Annulus Fluid: Diesel J Top of Sterling: 3320' Single w/heater stflng Tubing Hanger Offs "X* Nipple Brawn CC Safe~ ~t. Offs "XA" SIIcling ,Sleeve Baker FHL Ret. Pkr. 40M~ shear 3.00* 3 Blast J~ 8296'-3356' Brown Safety Jt. Straig~ pull 60M~shear Otis "XA* $ $ (o~enecl 6/1 Baker FHL Ret. Plm 781-36 DM 3.00' I111~l~/l~v,i ju~_ ,~:~! U! IUlULJi Tubing Locator Sub 2.4[]6' Baker Model 'D' Pe~n Pkr. 3~?~3' Seals Model 'D' E~enaea Bom Pkr. 2.406' Baker Shear Out Sub 2.00' ToD of Plug Otis' XN' Nipple Heater Sting Tubing Tall Casing and T~ Conauctor 36 · Surface 16" Intermecllate 10 3/4" Proa~ion Csg 7 · PnJductlon Tbg 2 3/8"(1) Heater 2 3/8"(2) 16.4' 75~ ,J-55 8RD 16.4' 55.5~t/51~t N-K] 81tO 16.4' 23d¥26f N-80/P110 8RD 16"4' 4.7~ N-80 EUE-8RD 16"4' 4.7~ N-80 EUE-SRD 16"4' 2.375" 2.375' 6.078" 3' 2.375' 6.078" 2.375' 3.437" 5.687" 3.234" 2.875' 2.375" 12 15 PBID 4157' Pedorcdions 3338'-3344' 4 34~ 5 3437'-3458' 4 3650'-3668' 4. 3732'-3734' 4 3815'-3825' 4 3866'-3875' 4 3901'-3921-' 4 4008'4014' 8 4020'-4024' 4 4056'-406g 4 4068'-4O78' 4 4105'-4111' 4 1125/85 8inker Dar 9~6~85 1.75" gauge ring 514/91 1.8' gauge ting ~I~/~ ~ ~.~s" /~ I,~ flulcl & sar~ at 4104' RKB X rdpple at 388g, nofll PX Dklg at 3881' I"dCB, i-io111 JI.B.11113/91 E'Lin~ BOPE's , Grease Head/ Hydraulic Packoff Lubricator Extension Manual Rams Swab Valve Double Master Valves , Wellhead · _ · . Bld~-Rm i Po~ Ogim Baz !~ Anoho~.g~ Alasim ~0 PM Znt~ials Charso Code Xerox copies to: nld~.Rm Please N-,nheryour Pages Use Only Black Ink Uae O~ly Clear/Defined Copies RECEIVED .I u L 14 1992 Alaska Oil & Gas Cons. Commission Anchorage COMPLETION REPORT- REMEDIAL AREA: Beluga River Field PROPERTY: Beluga River Unit WELL NO: BRU 212-25 LAND OFFICE: LEASE NO: APl NO: Anchorage ADL-17658 50-283-10025-00 LOCATION AT SURFACE: 2015' S 7 595' E of the NW Corner, Section 25, T13N, Rgw, S.M. LOCATION AT TOTAL DEPTH: Straight Hole ELEVATION: K.B. 15' SUMMARY TOTAL DEPTH: 5800' EFFECTIVE DEPTH: 4150' CASING:36" Cemented at 29' 16" Cemented at 288' 10-3/4" Cemented at 2364' 7" Cemented at 5776' RIG: DATE COMMENCED WORK: DATE COMPLETED WORK: RETURNED TO PRODUCTION: DATE: 12/84 Brinkerhoff Signal Rig #58 8/3/84 8/31/84 12/84 RECEIVED JAl £ 1985 Alaska Oil &.Gas Cons. Commission ~nchorage PAGE 8/3/84 BRU 212-25 Completed rigging up Brinkerhoff Signal Rig #58. Accepted rig at 2:30 a.m. Build 3% KCl-saturated NaC1 brine for workover fluid. 8/4/84 9.0 ppg Pumped 11 bbls. of 10.2 ppg saturated salt high vis pill down Production string (string #1). Tubing pressure was 3000 psi. Opened XA sleeve at 3320% Circulated out diesel fuel in the annulus and heater string 9.0 ppg salt water. Circulated well dead. Nippled down tree. 8/5/84 9.0 ppg Nippled up Class 1II BOPE. AOGCC and BLM waived witnessing test. Tested rams, choke manifold, kill line and safety valve to 3000 psi. Cheek valve did not test. Both strings of tubing came free with 70,000#. Set tubing strings back down to drain the stack. Could not land hanger or pull heater string free. Worked pipe without success. Pulled blanking plug from the production string. (Shoulder of blanking plug was hanging up on tubing hanger polished bore.) Heater string came free with top half of hanger. Circulated bottoms up. Pulled heater string. 8./6./.84 9.2 ppg Released 2-3/8" string #1 at Brown CC Safety joint at 3354% Circulated bottoms up. Pulled 2-3/8" string #1 from 3354% Changed rams - installed wear bushing. RIH with drill pipe and CC joint retrieving tool to recover remaining tubing. Released packer at 3363% Pulled up 5' with 15,000# overpull. Established eireulation. Circulated well dead. Pulled five stands of drill pipe - well flowing. Shut well in. 8/7/84 9.7 ppg Cireulated out gas. Increased mud weight to 9.7 ppg. RIH to 4105' and circulate bottoms up. Spotted a 10.2 ppg fluid loss pill across perforations 3437-4111. Filled hole through drill pipe every stand. Circulated bottoms up three times. Had a gas kick with eight stands out. Circulated out gas cut mud and increased mud weight to 9.9 ppg. "' -PAGE2 i 8/8/84 Recovered 24 joints 2-3/8" tubing, ?" packer, 2-3/8" Cameo D nipple. RIH with 6" bit. Clean out to firm bottom at 4161'. Replaced worn hydril element. Pick dp and Circulated bottoms up. 8/9/84 9.9 ppg Ran Schlumberger CET, CBL and Cased Hole Neutron from 4156'-2500'. RIH with test assembly for production test #1. Set peeker at 3945'. Had gas to surface in 19 minutes. 8/10/84 9.9 ppg Production Test #1. Interval 4008-4111'. 5 sets of perfs. 8/9/84. Rate MMCFD Surface Press. BHP ~ 3956' Hydrostatic , 2090 , 12/64" Choke 1225 1657 ?? 16/64" Choke 1250 1593 ?? 12/64" choke 1250 1592 1.7 20/64" Choke 1195 1471 3.1 26/64" Choke 1100 1347 4.1 33/64" Choke 840 1347 6.9 Buildup 1620 .,. Shut well in at well head. Shut in tool bled off drill pipe pressure. ppg mud. 8/.,1,1/84 Circulated 9.9 ppg mud until returns were 9.9 ppg. Circulated 9.9 9.9 ppg Shut in well for 9 hours, 33 minutes. Circulated bottoms up. POOH with test tools. Tagged fill at 4147'. Cleaned out fill to 4161'. Set retrievable bridge plug at 3750'. RIH with test assembly for production test #2. Filled first three stands with water (1222'). Set test tools at 3392' with packer at 3381'. Opened tool at 8:36 p.m. - had gas to surface at 8:46 p.m. Production Test #2. Interval 3420-3734'. 2 sets of perfs. 8/12/84. Surface Press. BHP ~ 3,390' Rate MMCFD Hydrostatic -- 1788 --- 4/64" Choke 1180 1474 1.5 ~ - PAGE 8/64" Choke 14/64" Choke 24/64" Choke Buildup 8/12/84 1240 1464 3.2 1180 1454 4.4 1090 1456 6.2 1767 - Shut in testing tool for 4~ hours. Circulated bottoms up. POOH with test tool. Separator had filled with fine sand and the temperature wells at the heater were badly sand cut. RIH open ended to 3748' - did not tag fill. RIH with test assembly for production test {{3. Set packer at 3690'. Opened test tool at 8..20 a.m. to test cemented perfs at 3732'-3734'. Had moderate blow progressing to vigorous blow. Pressure increased to 1350 psi. Interval flowed water wet gas. Water samples tested 160,000 ppm el indicating drilling fluid. Shut in test tool at 9515 p.m. Retrieved bridge plug from 3750'. Charts from prior bridge plug set at 3758' indicate the B.P. leaked inside the 7" casing or there is communication behind the 7" casing. 8/13/84 Set EZ drill bridge plug at 3748'. POOH with EZ drill setting assembly. RIH to 3690' with squeeze cementing assembly and set packer. Pumped 5 bbls. water ahead followed by 150 SX Class "G" cement then 5 bbls. water and 23 bbls. drilUng mud. Reverse circulated until mud weight in and out were 9.9 ppg. WOC. Had 4 bbls. cement in returns. RIH with 6" bit - tagged cement at 3696'. Cleaned out firm cement to top of EZ drill bridge plug at 3748'. Circulated bottoms up. 8/14/84 POOH with 6" bit. RIH and set Halliburton peeker at 3686'. Pressure tested cemented perforations at 3732'-3734' to 2100 psi - bled back to 1900 psi in 2 minutes. Held 1900 psi for 10 minutes, RIH with test assembly for production test #4 and set packer at 3690'. Used 1024' of water cushion. Opened tool at 2:34 p.m. Bubble - dead for entire test. Closed tool at 3:58 p.m. Set bridge plug at 3648'. RIH with test assembly for production test #5. Had 1211' water cushion. Positioned packer at 3596' in preparation to test 3650'-3668'. Rig shtlt down pending test heater repair. --~ - PAGE 4 ~ 8/15/8_4 lO ppg Rig shut down pending test heater repair until 5:30 p.m. Set peeker at 3595' to test 3650'-3668'. Opened hydrospring at 6:00 p.m. Had cushion to the surface at 6:16 p.m. Had gas to surface at 8:25 p.m. Did not have a sufficient rate to measure. Flowed gas to bubble bucket with flow diminishing from strong to medium blow at 9:38. Could not close tool or shear pump out sub. BHA had sand to the pump out 'sub. The pump out sub was sheared. Tagged fill at 3641' with bridge plug retrieving tool. Circulated out fill. Set bridge plug at 3560'. 8/16/84 Set test packer at 3430' for production test #6. Opened tool at 11:13 a.m. with a 2057' fresh water cushion' Cushion surfaced at 11:15 a.m. Recovered the cushion. Had gas to surface at 11:24 a.m. Diverted flow through test heater choke. Production Test #6. 8/16/84. Interval 3458-3437'. I set of perfs. Surface Press. BHp ,~ 3,441' Rate Water Hydrostatic - 1823 Drawdown -- 1302 1st Rate 1270 1491 .80 6gDh 2nd Rate 1270 1485 1.37 13gph 3rd Rate 1270 1483 2.15 20gph 4th Rate 1240 1476 3.46 20gph Buildup None Closed tool at 9:15 p.m. Sheared pump out sub. hydrospring. well dead. Performed 5 hour build-up. 8/17/84 Reverse Released peeker at 3430'. circulated above Circulated Surface Press. BHP ~ 3389' Rate Water Hydrostatic .... 1802 Drawdown --- 13112 18/6 4" Choke 12 4 0 14 76 1.1 6bph POOH with test assembly. Reset bridge plug at 3430'. RIH with test tools for production test #7. Set packer at 3378'. Use 1505' of 10 ppg mud (783 psi) for cushion. Opened tool at 3:06 p.m. Had eushion to surfaee at 3:09 p.m. Produetion Test #7. 8/17/84. Interval 3420 (WSD holes). Holes Producing. ..... - PAGE 5 25/64~ choke 1180 Buildup Shut hydrospring at 7:23 p.m. bridge plug. 8/18/$4, 1461 None Sheared pump out sub. 5.6 8.8bph POOH with packer and RIH with 6" bit - tagged 66' of fill on top of EZ retainer at 3750'. Circulated out fill. Drilled out retainer. Cleaned out to PBTD 4157'. Spotted a 25 bbl. fluid loss pill from 4157' to 3700'. POOH. Ran 7~ easing scraper to 4157'. Set EZ retainers at 3686' and at 3499'. Broke down formation with 10 bbls. of 10 ppg salt water at 3 BPM and 1500 psi. Cement squeezed perforations from 3650' to 3668' with 150 SX of Class "G" cement as follows: pumped 5 bbls. of fresh water followed by 121 e.f. of Class "G~ neat cement. Displaced cement with 2 bbls. of fresh water followed by. 29 bbls. of 10 ppg salt water. Displaced 14 bbls. at 3 BPM, 13 bbls. at 1~ BPM and the remainder at t BPM. Final squeeze pressure = 1700 psi. Reverse circulated D.P. -had no cement returns to surface. Set EZ retainer at 3374'. Broke down formation with 5 bbls. 10 ppg salt water at 1500 psi. Cement squeezed perforations 3458'-3437' and 3420' with 150 SX Class "G" cement as follows: Pulled up out of retainer and circulated 5 bbls. of fresh water follwed by 20 bbLs. of cement while holding 1000 psi back pressure on the annulus. Sting into the retainer. Mixed and pumped the remainder of the cement. Displaced with 2 bbls. of fresh water followed by 24 bbls. of 10 ppg mud to a final squeeze pressure of 1950 psi. Reverse circulated out 1 bbl. of cement. POOH. 8/19/84 Schlumberger perforated 3338' to 3344' with 4 - 1/2 JHPF with Hyperjet ii guns (1/2" holes). RIH with test assembly for production test #8. Had a 1760' fresh water cushion. Set packer at 3316'. Opened tool at 10:50 a.m. Had cushion to surface at 10:52 a.m. - gas to surface at 11:05 a.m. Production Test #8. 8/19/84. Interval. Surface Press. BHP ~ 3611' Rate Water Hydrostatic --- 1771 -- ~--PAGE6 Drawdown - 8/64 1250 4/64 1270 8/64 1230 23/64 1180 26/64 1150 Buildup Test was water and sand free. build-up. POOH. $/20/ 4 RIH in hole and tagged cement at 3365'. Drilled out retainer at 350(}'. retainer at 3687'. 8/21/8_4 1222 '-- -- 1442 2.8 Tr 1444 2.2 Tr 1400 4.58 Tr 1376 4.99 Tr 1366 5.06 Tr Closed tool at 10:20 p.m. Shut well in for 3 hour Drilled out retainer and cement to 3460'. Tagged cement at 3591'. Drilled out cement and Drilled firm cement from 3575' to top of EZ drill retainer at 3687'. Set champ packer at 3561'. Pressure tested perforations 3650'-3668' and 3437'-3458' to 1400 psi - bled off to 1270 psi in 10 minutes. Reset packer at 3374'. Pressure tested perforations at 3650'-3668' and 3437'-3458' and 3420' to 1400 psi - bled off to 1250 psi in 10 minutes. POOH with packer at 3687'. Cleaned out hole to 4149'. Ran Schlumberger CET and CBL from 4150'-2250'. hours. DriUed out EZ drill retainer at 3375'. Tagged cement at 3575'. 8/23!8_4 9.9 ppg Drilled out EZ drill retainer at 3501'. Tagged fill at 4148'. Cleaned out to 4152'. RIH with scraper to 4152'. RIH with a bridge plug, retrieving tool and packer. Tested perforations 3650'-3668', 3458'- 3437' and 3420' individually. WSO holes at 3420' held 1550 psi, perfs at 3650'-3668' held at 800 psi and bled off at 400 psi/min, to 350 psi, perfs at 3458'-3437' bled off at 250 psi/min. Attempted to test BOPE with bridge plug combinations - could not get them to seal. Set EZ drill retainers at 3687' and 3501'. ~22/8.4 9.9 ppg Set EZ drill retainer at 3375' to cement squeeze perforations 3650'-3668'. Pumped 5 bbls. ahead of 150 SX Class "G" cement followed by 2 bbls. water and 25 bbls. mud. Had a final pressure of 2000 psi. Reversed out 1 bbl. cement. ~VOC 10 ---~-~-~" - PAGE 7 8/24/8,4. 9.9 ppg Reperforated 4008~4014', 3901'-3921', 3866'-3876' and 3815'-3825' with Sehlum- ber~er's 4" Hyperjet II at 4 JHPF (1/2" holes). Made a bit and scraper run to 4149'. Set retrievable bridge plug equipped with a 5000 psi pressure bomb underneath at 3950'. RIH to 3771' with test assemblyfor production test #9. Had 1480' of water cushion. Opened tool at 8:52 p.m. Cushion fluid to surface at 9:00 p.m. Had gas to surface at 9:04 p.m. Production Test #9. 8/24/84. Interval 3815-2901'. 3 sets of perfs. Surface Press. BHP ~ 3795' ,.Ra.t,,e Water Hydrostatic --- 1839, -- Drawdown -- 959 -- 12/64" Choke 1440-1415 1695-163j~ 1.5 - 2.4 Tr. Buildup -- 1745 ~/ Washed choke out on first setting, producing a lot of sand. Choke at heater washed out. Shut well in at the well head at 11:50 p.m. produced trace of water and a lot of sand. Closed tool at 1:58 a.m. mud until returns gas free. POOH with test tool. 8/25/84 RIH with 6" bit to top of retrievable bridge plug at 3950' - no fill. assembly for production test #10 and set paeker at 3888'. Opened tool at 5:42 p.m. Had 1853' of water cushion - cushion to surface at 5:48 p.m. and gas flare at 6:13 p.m. Production Test #10. 8/25/84. Interval 3901-3921'. 1 set of perfs. Well Circulated 9.9 ppg RIH with test 8/26/84 9.9 ppg POOH with test tools at 7:07 a.m. Moved bridge plug from 3950' to 3888'. RIH with test tools for production test #11. Set packer at 3838'. Had 1853' of water Shut well in at well head at 4:05 a.m. Surface Press. BHP ~ 3913' Rate Water Hydrostatic _ u 1997 8/64 1358 1717 .97 Tr. 12/64 1320 1662 1.64 Tr. 16/64 1290 1570 2.18 Tr. 20/64 1265 1470 2.81 3bbls in slugs Buildup --- 1725 .. -- - ~-:- PAGE 8 cushion. Opened tool at 6:14 p.m. Had cushion to surface at 6:51 p.m. and gas to surface at 7:08 p.m. Production Test #11. 8/26/84. Interval 3866-3876'. I set of perfs. Surface Press. BHP ~ 3854' Rate Water Hydrostatic 1950 Drawdown 880 10/64 1020 1454-1612 .35-1.60 8.5B in 3~hr. 14/64 1099 1354 2.23 3B in ~ hr. Buildup 1444 Producing a lot of sand, washed choke out. of the I hr. 47 min. buildup. Production test after running tubing 8/31/84. String #1 Sterling and Beluga String # 1 Beluga Shut well in at the well head at 11:04 p.m. Retrieved bridge plug at 3888'. 8/27/84 Pressure still building at the end 3.2MMCF/D ~ 1100 psi 3.9MMCF/D ~ 1120 psi POOH with test tools at 12.'51 a.m. Set EZ drill retainer at 3888' and EZ drill cement retainer at 3838'. squeezed perforations 3866'-3876' with 200 SX Class "G" cement. Pumped 5 bbls. water followed by cement and displaced with 29.5 bbls. water and mud. Pulled out of retainer and reversed out colored water. POOH. RIH and set EZ drill retainer at 3780'. Cement squeezed perforations 3815'-3825' with 200 SX Class 'G' cement. Pumped 5 bbls. water followed by cement and displaced with 6 bbls. water and mud. WOC 10 hours. Tagged top of EZ drill retainer at 3780' - no cement on top of retainer. 8/28/84 9.7 ppg Drilled out EZ retainer at 3780' and firm cement to top of EZ drill retainer at 3838' and firm cement to top of EZ drill at 3888'. Set parker at 3838'. Pressure tested perforations 3866'-3876' to 1500 psi - O.K. Reset parker at 3780'. Pressure tested perforations 3866'-3876' and 3815'-3825' to 1440 psi - tested O.K. Drilled out EZ drill at 3888'. Cleaned out to ETD of 4148'. 8/.,2.9/84 10 ppg 9.9 ppg Cement · - PAGE 9 Ran and landed 2-3/8', 4?#, EUE 8RD produetion tubing. **See attached tubing detail.** Nippled down BOPE and nippled up tree. 8/30/84 Reverse circulated out salt water with diesel fuel. Hydraulic set packers. Shut in surface pressures 240 psi. Unload string #1, flow decreased to 0.3 bbls./hour for 2 ~ hours. Flow decreased to less than 0.3 bbl./hour. Set PX plug in Otis XN nipple at 3880'. Opened XA sleeve at 3387'. Fluid level dropped - no flow. Pulled PX plug at 3880' - both zones open. Flowed well at 0.6 bbls./hour for 2~ hours. Flow dropped to less than 0.3 bbl./hour. 8/31/84 The well unloaded before completing rig up of swabbing equipment. Flowed both zones for 5 hours. Sterling perforations (Upper Zone) open to production (3338'- 3344'). Beluga Perforations (Lower Zone) open to production (3901-3916, 4008- 4014, 4020-4024, 4056-4060, 4068-4078 and 4105-4111). Shut well in with flowing rate of 3.2 MMCF/D with 0 water production using a 23/64" choke. Had 1100 psi surface pressure. Produced the bottom zone for 7 hours. Produced at a stabilized 2 hour rate of 3.9 MMCF/D with 0 water production using a 20/64" choke. Had 1120 psi tubing pressure. Set a pump through 2-3/8' Cosasco BPV in both strings of tubing. Released Brinkerhoff Rig #58 at 12:00 midnight. BRU 212-25 PRODUCTION STRING KoBo Tubing Hanger Pup Jts. 2-3/8' 4.7# N-80 EUE 8RD 17 Jt~. 23/8" 4.7# N-80 EUE 8RD Otis X Nipple 2-3/8" 8RD 87 Jts. 2-3/8" 4.7# N-80 EUE 8RD Brown CC Safety Jt. 2-3/8" 8RD 1 Jr. 2-3/8" 4.7# N-80 EUE 8RD Otis XA Sliding Sleeve 2-3/8" 8RD Baker "FHL' Ret. Packer 40,000# Shear i Jr. 2-3/8' 4.7# N-80 EUE 8RD 3 Blast Jts. 2-3/8' 8RD 3" OD Brown Safety Jt. 2-3/8' 8RD, Strait Pull 60,000# Shear I Jt. 2-3/8" 4.7# N-80 EUE 8RD Otis XA sliding Sleeve 2-3/8" 8RD Baker "FHL" Ret. Packer 781036DM 16 Jts. 2-3/8" 4.7# N-80 EUE 8RD Otis XN Nipple 2-3/8" 8RD & Coupling X-Over Tubing Loeator Sub Baker Model D Perm Packer Seais - Model D Baker Shear Out Sub Length · 60' 13.87' 510.40' 1.17' 2679.30' 1.41' 29.91' 2.85' 7.30' 31.25' 60.10' 2.45' 29.34' 2.85' 7.65' 482.70' 1.30' · 98' 1.09' 4.05' 14.96' · 67' Depth 16.40' 17.00' 30.87' 541.27' 542.44' 3221.74' 3223.15' 3253.06' 3255.91' 3263.21' 3294.46' 3354.56' 3357.01' 3386.35' 3389.20' 3396.85' 3879.55' 3880.85' 3881.83' 3882.92' 3886.97' 3901.93' 3902.60' T.D.: 5800' Casing: 7' ~ 5'776, 10-3/4" ~ 2364, 16" ~ 288', 30" ~ 29' Perforations: A 3437 - 3458 C 3650 - 3668 D 4008 - 4014 4020 - 4024 E 4056 - 4060, 4068 - 4078 BRU 212-25 HEATER STRING Tubing Hanger 18 Jts. 2-3/8" 4.7# EUE 8RD N-80 Otis 2-3/8" XN Nipple 48 Jts. 2-3/8" 4.7# EUE 8RD N-80 TBG. Tail Length .60' 554.25' 1.28' 1461.77' Depth 16.40' 17.00' 571.25' 572.53' 2034.30' Hole Intar~al ~ $iz~ 1)~ BRU 212-25 Perforation Record As of 8/3' ~ ~. ~'~ Gun Under/ Over Balance Status St~rUng A Top at 3324' Baker FHL Packer at 3260' 3420 WSO 4 1/2" 12/13/62 333-3344' 4 1/2 8/19/84 Baker FRL Packer at 3393' 3437-3458'4 1/2" 12/23/62 Sterling B Top at 3485' Sterling C Top at 3632' 3650-3668' 4 1/2" 12/23/62 3732-3734' 4 1/2" 12/17/62 Beluga D Top at 3784' 3815-3825'4 1/2" 8/24/84 3866-3876'4 1/2" 8/24/84 Schl Carr~r Sch 4" Hypr2 Schl Carter Schl Carter Schl Carter Sch 4" Hypr2 Sch 4" Hypr2 Baker Model D Packer at 3890' 3901-392r 4 1/2" 8/24/84 Sch 4" Hypr2 4008-4014' 4 1/2" 12/23/62 Schl Carter 4008-4014' 4 1/2" 8/24/84 Sch 4" Hypr2 4020-4024' 4 1/2" 12/23/62 Schl Carter Beluga E Top at 4039' 4056-4060' 4 ti2" 4068-40T8' 4 1/2" 12/23/62 4105-4111' 4 1/2" 12/23/62 ~' WSO 4 l/Z" IZ/12/6Z 5~' W~ 4 1/2" ~12/11/62 ~lup F Top ~ 4~' ~lup G Top ~ ~31' ~lugs H Top ~ ~lug~ ITop~~ $chl ~rrer Schl Carter Schl Can-er Schl Can-er Ove£ Ovo£ Ove£ OVo£ OVe£ Over Over 5~er Over Over Over Sq'd Resq'd Open 12/20/62 8/18/84 Sq'd 8/18/84 Sq'd Sq'd WSO Resq'd Sq'd Sq'd 8/21/84 12/18/62 8/13/84 8/27/84 8/27/84 Open Open Olmn Open Reperf'd Open Open Open Sq'd WSO 12/13/62 Plg'd WSO 1-2/12/62 P~evious Rig Work Drilled by: O Coastal Drilling Company Rig #3 11/13/62-12/28/62 Workovers: No previous WELL SURVEYS: 11/13/62-12/28/62 Schlumberger Schlumberger Schlumberger Schlumberger Schlumberger Induction - Electrical log, interval Sonic log, interval Mierolog-Caliper, interval Continuous Dipmeter, interval Cement Bond log, interval Neutron Collar log, interval Schlumberger Schlumberger Casing Collar log & Perforating Record Baroid Daily Mudlog, interval 288 - 5804' 290 - 5801' 290 - 5802' 290 - 5805' 2300 - 5730' and Surface - 5221' 2300 - 5732' 290 - 5800' 8/3/84-8/31/84 Schlumberger CET log 4156 - 2500' Schlumberger CBL log 4156 - 2500' Schlumberger Cased Hole Neutron 4156 - 2500' Schlumberger CET log 4150 - 2250' Schlumberger CBL log 4150 - 2250' 8/9/84 8/9/84 8/9/84 8/23/84 8/23/84 DRILL STEM TESTS: HCT #1, WSO Test at HCT #2, interval HCT #3, interval HCT #4, interval 5506' 4246 - 4248' 3732 - 3734' 3732 - 3734' 'I TRANSMITT,', ,~ND ACKNON].EDCEMENT OF ~ECF. XPT HATERIAL - (ALASKA) -- CW~E_V ~ot4 0.6.~. ) I dc_. -OPEIm,. _ iii ii i i ii ~~v~l~ U.~-~. I~o · TRANsH~,L AND ACKNON'LEDGEHENT OF RECE, ,' OF HATER'tAL - (ALASKA) -~: A.O. DATE DEPT.: PLACE: HE FOLLO~iN~ IS A LIST OF MATERIAL ENCLOSED HEREIN. FD- Folded R - Rolled S - Sepia F - Film - Xerox B - Blueline PLEASE CHECK AND ADVISE IMHEDIATELY. z, c~5~ ,,C~IL ~. ?_~/VA,~,A~u~ i ii ,..¢.u>J I ~u~ 2_ ii i ': ...... , ,..:. C ..........SlOrl · RECEIVED 8Y · NE:MARKS ON OTHER SIDE:, THIS SHEET ~ON U.$~. INC. BOX 7-839 'ANadORAGE, ALASKA 99510 I_ STATE Of ALASKA ~ ALASKA,OIL AND GAS CONSERVATION ~,OMMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL [] OTHER [] 2. Name of Operator 7. Permit No. Chevron U.S.A. Inc 62-033 3. Address P.O. Box 107839, Anchorage, AK 4. Location of Well 99510 2015' S. & 595' E. of the N.W. Cor., Section 25, T 13N., R.~.9W , S.M. 8. APl Number 50-- 283- 10025-00 9. Unit or Lease Name . Beluga River 10. Well Number 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. 15' K.B. ADL- 17658 -~2. Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data BRU 212-25 11. Field and Pool Beluga River - Sterling and Beluga NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] ~ Perforations [] Altering Casing Stimulate [] Abandon [] Stimulation [] Abandonment Repair Well [] Change Plans [] Repairs Made I~ Other Pull Tubing [] Other [] Pulling Tubing (~) (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) E3 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). sEP ~[S COBS, CO~'tSS~0~t AnchOrage SEE ATTACHED Signed~-~- ·~ Title Area Engineer The space below fOr Commission use Conditions of Approval, if any: Approved by .... Form 10-403 By Order of COMMISSIONER the Commission Date Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate 1) Moved in, rigged up Brinkerhoff Signal Rig 58. NU BOPE and tested to 3000 psi. 2) Killed well with 10.0 ppg 3% KCL and saturated NACL brine. Pulled production tubing. 3) Logged with Schlumberger's CBL-CET and cased hole neutron from 4156' to 2500'. 4) Production tested perforations at: 4105'-4111', 4078'-4068', 4056'-4060', 4020'-4024', 4008'-4014', 3732'-3734', 3650'-3668', 3437'-3458', and 3420'. 5) Perforated and production tested at: 3338'-3344' 3815'-3825' 3866'-3876' and 3901'-3921'. Reperforated 4008'-4014'. 6) Cement squeezed perforations 3420' 3437'-3458' 3650'-3668' 3732'-3734' 3815'-3825', 3866'-3876' because'of sand and water production. Logged with Schlumberger's CBL-CET from 4150' to 2250'. 7) Ran 2 3/8" production tubing with packers at 3890', 3393', and 3260'. Ran 2 3/8" heat string to 2034'. Nippled down BO?E and ~ippledup tree. Circulated out brine with d~esel. Set hydraulic packers. 8) Unloaded diesel and production tested Sterling perforations at: 3338' to 3344' and Beluga perforations at: 3901'-3921', 4008'-4014', 4020'-4024', 4056'-4060', 4068'-4078', and 4105'-4111'. Maximum rate 3.2 MMCF/D at 1100 psi. Closed selective sleeve and isolated Sterling perforation 3338' to 3344'. Production tested Beluga perforations 3901'-3921', 4008'-4014', 4020'-4024', 4056'-4060', 4068'-4078', and 4105'-4111'. Maximum rate 3.9 MMCF/D at 1120 psi. 9) Shut in well. Rigged down and moved off rig. 10) Installing production facilities in preparation to produce from the Beluga formation. Estimated completion date: 10/1/84. RECEIVED SEP l 81984 Alaska Oil & Gas Cons. Commission Anchorage ,,~ STATE Of ALASKA f~ ALASK'~ OIL AND GAS CONSERVATION ~OMMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL I~ 2. Name of Operator t 7. Permit No. Chevron U.S.A. Inc. 62-033 OTHER [] 3. Address P.O. Box 107839, Anchorage, AK 4. Location of Well 99510 8. APl Number 50-283-10025-00 9. Unit or Lease Name Beluga River 2015' S & 595' E of the NW Corner, Section 25, T.13 N., R.9 W., S.M. 5. Elevation in feet (indicate KB, DF, etc.) 15' KB 6. Lease Designation and Serial No. ADL-17658 10. Well Number BRU 212-25 11. Field and Pool Beluga River - Sterling & Beluga 12, Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate ~ Alter Casing [] ~ Perforations [] Altering Casing [] Stimulate [] Abandon [] Stimulation [] Abandonment [] Repair Well I~ Change Plans . [] Repairs Made [] Other [] [] Other Squeeze F~ Pulling Tubing [] Pull Tubing (Note: Report multiple completions on Form 10,407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.10§-170). 1) 2) 3) 4) Cement squeeze perforations: 3732-3734~;3650-3658'; 3437-3458'; 3420'. Perforate and test 3338-3344. Cement squeeze if wet. Perforate and test 3815-3825'; 2866-3876'; 3901-3921'. Cement squeeze if wet. Run 2 3/8" production tubing with packers at 3250'; 3390'; and 3890' to produce ; perforations 3338-3344', segregate cement squeezed perforations: 3420'; 3437-3458' 3650-3668'; 3732-3734'; 3815-3825'; 3866-3876' and produce perforations: 3901-3921'; 4008-4014'; 4020-4024'; 4056-4060'; 4068-4078'; 4105-4111'. RECEIVED SEP 0 AlasKa 0il & Gas Cons. Commission Anchorage As per verbal approval from Lonnie Smith on 8/13/84, 8/17/84, and 8/28/84. 14. I hereby certif~~the best of my knowledge. Signed~, 4~__ ~ Title Area Engineer The space below for Commission use Date ! '1 ' Conditions of Approval, if any: I~IGlltAL $1~li[ll Approved by Form 10-403 COMMISSIONER Approved Copy Retur? / By Order of the Commission Submit "Intentions" in '~'riplicate Rev. 7-1-80 and "Subsequent Reports" in Duplicate , i STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION CuMMISSION SUNDRY NOTICES AND REPORTS ON WELLS DRILLING WELL [] COMPLETED WELL [] OTHER [] 7. Permit No. 62-033 2. Name of Operator Chevron U.S.A. Inc. 3. Address P, O. Box 107839, Anchorage, AK. 4. Location of Well 2015' S & 595' E of the NW Cor., Section 25, T13N, R9W, S.M. 5. Elevation in feet (indicate KB, DF, etc.) 15' K.B. 12. 99510 I 6 . Lease Designation and Serial No. AD[-17658 8. APl Number s0-283-10025-00 9. Unit or Lease Name Beluga River 10. Well Number BRU 212-25 11. Fiel~ and Pool Beluga River- Sterling & Beluga Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] ~ Perforations [] Altering Casing [-J Stimulate [] Abandon [] Stimulation [] Abandonment [] Repair Well ~ Change Plans [] Repairs Made [] Other [] Pull Tubing ~ Other [] Pulling Tubing [] (Note: Report multiple completiOns on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, fOr Abandonment see 20 AAC 25.105-170). See attached. This work will begin on or about July 30, ]984 ...... ent Wo~l~ l~eport¢cl RECEIVED JUN 2 2 19 4 Alaska 0il & Gas tuns. Commission Anchorage Signed. . Title Area EnKineer The space below for CommiSsion use Date Conditions of Approval, if any: Approved by BI' L011111[ C. SMITH Approved Copy Returned By Order of COMMISSIONER the Commission Form 10-403 Rev. 7-1 Submit "Intentions" in 'J'riplicate and "Subsequent Reports" in Duplicate PROPOSAL FOR WKLL OPKRATIONS- PRO 316-1 SBU 211-SS ILKMKDIAL .JOB WELL: BRU 212-25 · FIELD: Beluga River Unit 2015' S & 595' E of N.W. Corner LOC.: of Sec. 25 T13N R9W Seward R&M TYPE WELL: Gas l~oducer OBJECTIVE*. Clean out the sand fill, flow test the individual zones, isolate the Beluga and Sterling zones and return to production. WELL DATA:K.B. 15' (42, elev.) T.D. 5,800' PBTD +_4,150' CASING*. 7" ~. 5,776', 10 3/4" ~. 2,364', 16" ~. 288', 36° ~ 29* LINER: None TUBING: 2 3/8' production stcing to 4105', 2 3/8' heat strir~ to 2031' PACKER: Brown 7' HS-16-1 (~ 3,363* PERFORATIONS.' A 3,437'-3,458', C 3,650'-3,668', D 4,008'- 4,014', 4,029'-4,024', E 4,056'-4,060', 4,068'-4,078', 4,105v-4,111', 3420** and 3732'-3734** *Squeezed with cement. Notes= (A) (B) (c) Sand fill inside 2 3/8" tubing tal~ed at 3,495* on 10/26/83. Estimated formation pressure 1,728' psi ~ 3,774* TYD MPP for a 0.458 psi ~radient. _ Casing Detail: K,B. Depth Above K.B. 33 joints 7" 23# N-80 BT R3 1 joint 7" 26# P-110 8Rd DV collar 66 joints 7" 23# N-80 BT R3 1 joint 7" 26# P-Il0 8Rd DV collar 32 joints 7" 23# N-80 BT R3 2 joints 7" 26# P-110 8Rd including shoe and float collar Casin~ cemented at 2.00* 1,427.00' 41.19' 2.08* 2,819.16' 39.86* 2.08' 1,362.78' 83.92' 5,776.07 1,425.00' 1,466.19' 1,468.27' 4,287.43~ 4,327.29~ 4,329.37* 5,692.15' 5,776.07* Blowout Prevention Consideeations The subject weU is a gas weU with one producing string and a heater string. The 2 3/8" production string has sand fill to 3495*. This well may be diffiault to kill. Caution must be exercised while killing and pulling this well. Drilling crews should be alerted at all times for gas kicks and be familiar with the procedures for handing kicks. Mud weight up material should be on location at all times. RECEIVED JUN 2 2 1984 Alaska Oil & Gas Cons, Commisslon Anchora§e PROPOSAL FOR WELL OPKRATION8- PRO.-316-1 BRU 1l~-.:~S ILKM~IAL JOB 1984 PROGRAMz Prior to moving in the workover rig, clean the sand out of string I, and if possible the 7" easing to 4,150' using ooiled tubing. 1) Prepare the location for the workover rig. Build an earth flare pit away from the rig -no reserve pit is allowed. Set pump-through back pressure plugs prior to moving in the rig. 2) Move in and rig up the workover rig. Rig up to recover all fluids and cuttings' 3) Mix up a lightly treated chrome-free lignosulfonate mud with; 10.0 - 10.5 ppg weight 30 - 45 see/qt viscosity 4 - 6 ee fluid loss (See mud program for more detail.) 4) 5) Remove pump-through BPV in strings I and II. Open the Cameo sliding sleeve ~ 3,320' with wireline. Circulate heat oil out of the annulus and string H with kill fluid through the sliding sleeve at 3,320'. Use the heat oil for unloading fluid on production tests if possible. Set BPV in string I and IL ND tree, install Gray Tool blanking plugs in both tubing hangers. N.U. Class III BOP, and test BOP stack to 5,000 psi. Alert BLM and AOGCC 24 hours prior to the BOP test. Have a wear bushing on location and install when possible' 6) Remove the blanking plugs and kill each string individually. Pull the 2 3/8" heat string. 7) Remove the BPV in string L Release the Brown CC safety joint at 3,354' and recover the 2 3/8" production string. 8) RIH with a CC it. retrieving tool or an overshot on drill pipe with jars and drill collars as needed. Release the 7" x 2 3/8" Brown H$-16-1 packer and recover the remaining tubing. 9) Clean out to the PBTD of 5,722' with a bit and scraper. Circulate the hole clean. 10) Run a cement bond evaluation tool from PBTD to 2,500'. Run a multi-spaced neutron log from PBTD to 2,500'. 11) Rig up to production test the well using a mobil test separator and heater. Lay a flare line to the flare pit and rig up a Baker tank or test tank to recover any fluids while unloading the well. Recover all unloading diesel and reuse if possible. RECEIVED J U N 2 21984 Alaska Oil & Gas Cons. Commission Anchorage 12) Production test the intervals noted below: A) On the production tests use drill pipe, a 7" Baker Model G lock set retrievable bridge plug, and a 7n retrievable packer or similar equipment. Set the bridge plug at the required depth, pull up hole to the required depth of the packer, displace the tubing with diesel to the top of the packer and set packer. Rig up a test manifold. Unload the diesel and mud into a Baker or test tank until gas reaches the surface, turn the well into the the separator and flare the dry gas. Obtain four separate flow rates of a minimum of 2 hours each after the well cleans up. The first flow rate should be 0.5 MMCF/D and the other rates are to be determined by the results of the previous test. (Note: Excessive draw down - 500 psi less than static-has caused sand production in other wells. Keep the draw down to less than 400 psig of the initial 0.5 MMCF/D rate.) Record produetion rates (MCF/D), tubing pressures, sand and water rates, static pressure, choke sizes, etc. After the test, kill the well, release the packer and bridge plug, and pull up hole for next test. B) If the intervals including the squeezed holes make water, retest the squeezed holes only. c) Test Zone Type Interval Bridge Plug Depth 1 ' DE Flow 4056'-4111' and None ' 4008'-4024' 2 AC Flow 3650'-3668' and + 3700' 3437'-3458' Packer Depth + 3700' + 3380' 13) Supplemental program to follow for completion detail. (A) The completion design will be dependent on the results of the tests. The tentative completion design is to segregate the Beluga from the Sterling with single packers at +3375', and +3?00'. If the sand production is coming out of the Beluga sands as-believed, the Beluga may be abandoned below a cement retainer and the Sterling, produced below a single packer at +3375'. J. A. CONN 4/20/84 ~ CHEVRON'U.S.A.,INC.· TRANSHITI..-' AND ^CKNOI4LEDGEHENT OF RECEXPI .,F HATER~.AL - (ALASKA) DEPT.: ALAS~ O I L ~ d-A5 PLACE: $001 POR Cm PI ,dE_ FD- Folded it - ~olled S - Sepia - Film X - Xerox B - Bluel~ne THE FOLLOIFING IS A LIST OF HATERIAL ENCLOSED HEREIN. PLEASE CHECK AND ADVISE It'IHEDIATELY. BELUGA R~VE-R 'W ~LL "~ E, Rd . _i°' IL ' Ai~,~k. Oil & 6as uonE.-c6mm'ission Anchorage ill i =,l, ii RECEIVEO 8Y i iii llll i I I I REMARKS ON OTHER SIDE, THIS SHE'ET BY N.P. 'F3LAcKM~ (~IEVRON U.$,A./:NC. BOX 7.839 'ANO'IOI~GE, ALA~A ~510 STATE of ALASKA DEPARTMENT OF 'NATURAL RESOURCES Division of Oil and Gas Conservation TO: J--- FROM: HEHO TO FILES Harry W. Kugler Petroleum Geologist DATE , June 13, 1977 SUBJECT: Be 1 uga Ri ver Fi e 1 d. Dave Courtis, Union Oil Company of California, called this date to report that there were no mud logs-in the State files of'the following wells: Socal BRU' #232-4 ~ Completed in 1963 ~---~-o_cal _BRg 212-25.,)Completed in 1962 S-o~i- BRU 233-27 .Completed in 1963 Socal BRU 212-24 Completed in 1973 Socal BRU 224-13 Completed in 1974 He stated that he believed our regulations are such that we should request Socai (CheVron) submit these logs if they were run. I reported, after consultation wi th the Director and staff members, 'that our interpretation of the regulations were not the same and we Would not require the mud logs'. Upon hearing this, he stated he would turn the matter over to Union's land department for their interpretation and the land department would be in touch with us. CC~P~ION I~PORT - I~E~ ~ Petroleum Branch Division of Mines and Minerals Ala~kc Dept. of Natural Resourcel STANmU~ OU~ C~AN~ OF CAL~ZA - W~S,, ,,am~ o~mTzoNs, ueo.. (mmm~OR -- -' I _- - ' .i Ill ~ ...... . - ,11 I Il f I[ I - J I J III ~. '" I - - I . Ill AI~..~: ~ NO.: LOCATZON: CoOk Inlet, Alaska LAND OFFICE: .Anchorage Lease No. A-029658 Belu$~ River Unit /o BRU 212-25 Section 25, Township 13 North, Range~West, Seward B~ Surface: 2015' SOuth and 595' East from .Northwest Corner of Section 25. ELEVATION: ~2' K.B. DA~: April 12, 1963 K. B. is 15' above ground. C. ~ 6~T~N,- District S~rin%ehclent DRILLED BY: Coastal Drilling Company, Rig ~3 'DA'~ ~~ D~: November 13, 1962 DATE ~LE~ED DRILLiNg: December 28, 1962 DATE OF INTITIAL P~X~ION: Shut in pemdlng installation of production facilities. 81UMARY TOTAL I~PTH: 5800' PLU~S: NONE Cement 4150 - ~204' EM retainer at 4204' Cement ~2~0 - 4280' Cement 5220 - 5379' EM retainer at 5379' Cement 5722 - 5776' 36" cemented at 29'' 16' cemented at 288' 10 3/~" cemented at '2364' 7" cemented at 5776' CCMPLETION ~EPO~ BELUGA RIVEa U~IT 212-2~ STANDARD OIL C(MPANM'~OF CALIFORNIA, W. O. I. - OPERATOR November 1), ,,1962 SpudAe d at 3: O0 A.M. Drille~ 14 3/4" hole to 290' and opened hole to 20". Reamed 20" hole to 290'. Pan and cemented 9 joints 16", 75~, J-55, 8R c~sin~ at 288' with 300 sacks cement. Installed Class III BOPE. Tested BOPE with 1800 psi - OK. Drilled out cement 268 - 290' an~ drilled 14 3/4" hole to 866'. Baroid mu&logging unit commenced logging at 290'. November 19, 1962 lled 14 hole to 1517 - 288'. ove ,.mbe , 20, Drilled 14 3/4" hole to 2123'. Ran Schlumberger Induction - Electrical log 79 - 81 pcf mud Ran Induction - Electrical log 2123 - 1513'. 74 - 78 pcf mud Nq..ve..mbe. r' 21, 1962 Drilled 14 3/~".hole to 2364'. Ran Induction - Electrical log 2369 - 2129', Sonic log 2367 - 290', Microlog-Oaliper 2369 - 290' and Continuous Dipmeter 236~ - 288'. Conditioned mud. 76 pcf mud November 22, ..1962 Ran and cemented 58 Joints 10 3/4" casing at 236~' with 950 sacks cement. Top 37 joimts or Bottom 21 joints or Above K. B. Casing cemented at 1520 ' 86' 10 3/¥', 51~, N-80, 8R equipped with shoe and float collar. No~vember .25~ . 26, 1962 Installed Class IV BOPE and tested with 2500 psi - Drilled out cement an~ shoe an~ drilled 9 5/8" hole to '2951'. 74 - 75 pcf mud PERFORATING 5- ;" holes at '~" holes per foot ~" holes per foot ~" holes at ." holes at ." holes per foot Page 2. 3420' squeezed. 3732 - 3734' squeezed. 42~6 - 4248' cemented off. 4280' squeezed and cemented off. 5506' cemented off. 3437 - 3458' 3650- 3668' ~o56 - ~o6o' 4068 - 4078' 4105 - q'lll' SURVEYS: 1. Schlumberger Induction - Electrical log,, interval 2. Schlumberger Sonic log, interval 3. Schlumberger Microlog-Caliper, interval Schlumberger Continuous Dipmeter, interval 5- Schlumberger Cement Bond log, interval 6. Schlumberger Neutron Collar log, interval 7. Schlumberger Casing Collar log and Perforating Record 8. Baroid Daily Mudlog, interval 288 - 58o4' 290 - 5801' 290 - 5802' 29O - 5805' 2300 - 5730' and Surface - 5221' 2300 - 5732' DRILL STEM TESTS: HCT ~1, WSO Test at ~3T ~2 interval HOT ~3; interval HOT ~4, interval 55o6' 3732 - 373~' 3732 - 373~' COMPLETION EEP0~ BELUGA RIVER UNIT 212-25 Section 25, T. 13 N.~ R. 10 W.~ Sewar. d B & M S~A~D o~ C~A~"o~ 'CA~O~'~ w. ~. ~I'. '-' O~A~ Page 4. November 28 - 30, 1962 Drilled 9 5/8" hole to 5o3o' 74 - 76 pcf mud ~c~mber~ 4 1962 Ran Schlumberger Induction - Electrical log 4589 - 2369'. Drilled 9 5/8" hole to 5331' · 75 pcf mud December 2, 1962 Drilled 9 5/8" hole to 5800' T.D. Baroid mud.logging unit released. 75 pcf mud Dece~mber ,3~,, 1~62 Ran Schlumberger Induction - Electrical log 5804 - 2366', Sonic log 5801 - 2366', Microlog-Caliper 5802 - 2366' and Continuous Dipmeter 5800 - 2366'. Circulated. 76 pcf mud ~ember 4,,,, ....1962 Conditioned hole for 7" casing. 75 - 76 pcf mud Dec.crab. er 5, 1962 Laid down drill pipe and ran 7" casing. 76 pcf mud .December .6, 1962_ Ran and cemented 135 joints 7" casing at 5776' with 300 sacks cement around shoe, 450 sacks through DV collar at 1466' and 200 sacks through DV collar at 4327'. Total 950 sacks cement. Casing detail: Above K.B. .:~- 33 Joints 7" 235 N-80 BT R3 1 joint 7" 26~ P-110 8Rd DV collar 66 Joints 7" 23~ N-80 BT R3 i joint ?" 26~ P-no 8~d DV collar 32 joints 7" 23~ N-80 BT RS 2 joints 7" 26~ P-110 8Rd including shoe and float collar Casing cemented at Depth - 2.00' 1427.00' 1425. 41.19' 1466.19' 2. o8' 1468.27 ' 2819.16 ' [I.287.43 ' 39- 86' 4327.29 ' 2.08' 4329.37' 1362.78' 5692.15 ' 83.92 ' 5776.07' 5776.07' Removed BOPE and landed casing. December, ~ ?,. -__ 8 ~,, !962 Standing cemented and waited on equipment. COMPLETION BELUGA RIVER UNIT 212-25 Section 25~ ,T~, ,13 ,N,,.,~, ,R. !© W.~ ,Seward,. B STAN~ OIL COMPANY OF CALIFORNIA - W. O. I. Page 5. Dec,e~.b,,er,,9~ .lp62 InStalled Class III BOPE and tested with 2000 psi - OK. .De~cember.,' 10~ 1962 Ran 6" bit and drilled out DV collars at 1466' and 4~27' and tested with 2000 psi - OK. Cleaned out to 5722' and circulated~ Ran Neutron Collar log 5732 - 2300' 76 per mud Ran Cement Bond log 5730 - 2300'. Ran Schlumberger Carrier Gun and shot 5 - z holes at 5506'. HOT ~1, WSO test at 5506'. Tool assembly: 2 outside BT re- corders, 4' of .2 7/8" perf'd tail pipe, 7" ty~e "C" hookwall packer, VR safety joint, hydraulic Jars, 2 inside BT recorders, hydrospring tester and dual closed in valve. Ran on 5340' of 3½" DP and 121' DC. Used no water cushion. Set packer at 5457' with 17' of tail to 5474' at 1:25 P.M. Opened tester at 1:27 PA4. for 4 rains, pressure release. Very faint blow of air. Shut in tester at 1:31 P.M. for 28 mins. ISI pressure period. Opened tool to surface at 1:59 P.M. for 61 rains, flow test. No FSI. Immediate moderate to strong blow of air. Turned to flare at 2:06 P.M.- air. Turned back to bucket with weak blow at 2:20 P.M. Pulled loose at 3:00 P.M. Recovered 300' net rise of 7~ to 76~ drilling mud (2~ bbls. ) Final pressure data: Depth Gauge IE ISI IF FF F~ Top inside ~ 54~1' 29il ~ 42~-~ 4~!~8 2-~ Bottom inside 5445' 2910 2615 37/72 42/136 2889 Top outside 5466' 2889 2636 119 906 2873 Bottom outside 5470' 2927 2613 47/130 48~ 2912 COnclusion: Plugging and unplugging first 40 rains. Plugged during last 20 rains D~.cembeM .12, 1962 Set I~ retainer at 5379'- Unable to break down holes with 4600 psi. Equalized 32 sacks of cement on top of retainer at 5379'. Pulled to 5100' and circulated. Pulled out. Ran Schlumberger carrier gun and shot 5 ~ ~" holes at 4280'. Set ~2~ retainer at 4165'. Broke down formation with 1900~ psi at 1.5 bbl/min, rate. ~queezed holes at 4280' with 100 sacks cement. Final pressure 2200~ psi. Cement in place at 9:30 P.M. December !3~ 1~62 Brohe down holes at 4280' with 2000~ psi (at 3:15 A.M. ) and resqueezed with 1OO sacks cement. Final pressure 32OO~ psi. Cement in place at 4:40 A.M. Shot 5 - ~" holes at 3420'. Set I~ retainer at 3297'. Broke down holes at 3~20,' with 1~00 psi and squeezed with 160 sacks cement. Final pressure 1100~ psi. Cement in place at 4:35 P.M. Broke down holes at 3420' with 1650~ psi and resqueezed with 91 sacks cement. Final pressure 3200~ psi. Cement in place at 11:30 P.M~ ,77 pcf mud COMPLETION REPORT STANDARD OIL COMPANY OF CALIFORNIA, Wo O. I. - OPERATOR Decembe. r ..14~ 1962 Page 6. Drilled out retainer at ~297' and cement 3400 - 3420'. Drilled out retainer at 4165' and cement 4187 - 4250'. Pressure tested holes at 3420' with 2000~ psi. Would not hold. Set a I~ retainer at 3266'. Broke down holes at 3420' with 2800~ psi and squeezed with 50 sacks cement. Final pressure 1600 psi. D?~c,?m,b, er 15, _196,,2 Cement in place at 12:30 A.M. Circulated and waited on cement. Pressure tested holes at 3420' with 2600 psi. Eeld OK. Drilled out retainer at 3266' and cleaned out-to ~250'. Drilled hard cement to 4280' and cleaned out to 5220'. Pressure tested holes at 4280' with 2000~ psi. Would not hold. _~December' ,,1..6~ ~-9~21 77 pcf mud Ran cement bond log 5220' - surface. Set DM retainer at 4270' and pressure tested holes at 4280' would not bolA. Shot , ~ holes per foot 4246 - 4248'. ECT ~2, 4246 - 4248'. Tool assembly: 2 outside BT recorders, 4' of 2 7/8" perf'd tail pipe, 7" type "C" hookwall packer, VR safety Joint, hydraulic Jars, 2 inside BT recorders, hydrospring tester, and dual closed in valve. Ran on 4190' of 3½" drill pipe. Used no water cushion. Set packer at 4215' with 17' of tail to 4232'. Opened tester at 5:38 P.M. for 4 rains, pressure release. Medium blow of air during pressure release. Shut in tester at 5:42 P.M. for 50 rains. ISI pressure period. Opened tool to surface at 6:34 P.M. for 76 mins. flow test (5 rains, purging). Shut in tool at 7:55 P.M. for 60 rains. FSI pressure. Weak blow of air for 5 rains, then dead. Pulled and reset packer at 6:45 P.M. - reopened at 6:50 P.M. to open bypass and purge perforations~ Weak blow of air for 2 rains, dead balance of test. Pulled loose at 8:55 P.M. Re- covered 60' net rise drilling mud (76~). Pressure data: Depth _Gauge IH ISI IF FF FSI FH ~ttom inside 4203' 2~5 156 35/38 35/52 269 2253 Top outside 4222' No ~co~i~s, clock st~ped. ~ttom outside ~226' 2307 171 59/62 53/74 2~ 2278 Conclusion: Charts indicate tester open. .December 17, 1962 Very tight formation. Set I~ retainer at 4204' and shot 4 - ½" holes per foot 3732 - 3734'. 77.5 pcf mud ECT ~3, 3732 - 3734'. 'Tool assembly: 2 outside BT recorders, 4' of 2 7/8" perf'd tail pipe, "7" type"C" hookwall packer, VR safety Joint, hydraulic jars, 2 inside BT recorders, hydrospring tester and dual closed in valve. Ran on 3513' of 3½" drill pipe and 92' drill collars. U~ed no water cushion. Set packer at 3689' with 15' of tail to 3704'. Opened tester at 1:25 P.M. for 5 rains, pressure release. Medium light blow of air. Shut in tester at 1:30 P.M. for 45 mime. ISI pressure period. Opened tool to surface at 2:15 P.M. for 110 mime. flow test. Shut in tool at 4:05 P.M. for 50 rains. FSI pressure. COMPLETION REPORT - BELUGA RIVER UNIT ~212-~5 Section 25, T. 13 .N. ,_ R. 10 W., .Se_ward, ~ .&. M. STANDARD OIL COMPANY OF CALIFOENIA, W. O. I. - OPERATOR Page 7. Pulled packer loose at 4:55 P.M. with 6000~ over weight of drill Pipe. Gas to surface in 2 sins. at 30 MCF/D rate, gradu~!ly decreasing to l0 MCF after 40 sins., then. to a very weak blow. Possible Dlugging - purged perforations at 3:35 P.M. Reopened tester at 3:40 P.M. Medium blow of gas (22 MCF/D) grad- ually decreasing to a weak blow of gas. Pulled packer at 4:55 P.M. Recovered 2600' net rise. First stand recovered 76~ rat hole mud. 2nd stand recovered 102~ sandy mud, gassy and frothy - tried to head. Put on flow head and back- scuttled rise. Estimated 18.9 bbls. recovery. "~ackscuttled 13 sins. - first part (±25~) was 76~ mud grading into sandy watery mud--3 68 ohm/m at 80OF - 125 G/G, then muddy sandy water testing 1.96 ohm/m at 80°'= 140 G/G chlorinity followed by backscuttled drilling mud. Final pressure data: Bottom inside 3678' 1998 1668 145/510 166/1657 1657 1958 Top outside 3697' 1992 1632 272/1199 267/1659 1659 199~ Bottom outside 3701' 1988 1650 270/1201 246/1662 1662 1950 Ran bit and casing scraper to 77.5 pcf mud ~December 1.8.~,.' !96Z Ran open ended drill pipe to 4197' and equalized 20 sacks of cement. Set Halliburton cast iron br!d~ ~ plug at 6~'. Broke down formation with 1300 psi and squeezed ~-~'i'-'~34-~--~-~ 150 sacks cement. Stood cemented 4 hours. Broke down holes with ~0~ psi and resqueezed with 100 sacks cement. Cement in place at 6:00P.M. ~ o~ ~. December 19, !9~2 Ran bit and casing scraper and drilled out bridge plug at 3605'. Drilled cement 3610 - 3736', cleaned out to 4142' and drilled cement to 4150'. Pressure tested holes at 37~2 - 3734: Broke down at 1700~ psi. Set I~ retainer at 3603' and pressure tested to 2300 psi. Held OK. Closed pipe rams and pressure tested above retainer. Fluid pumped away at 1500 psi. 77.5 pcf mud .December 20, 1962 Set I2d retainer at 3295'. Broke down holes at 3420' wit~ 1500 psi and squeezed holes with 150 sacks cement. Final pressure 2600 psi. Cement in place at 6:30 A.M. Stood cement 12 hours. Drilled out retainer at 3295' and drilled firm cement to ~420'. Cleaned out to 3600'. 78 pcf mud December 21, ,,,196,~ Pressure tested holes at 3420' with 2000~ psi - OE. Drilled out retainer at 3603' .and cleaned out to ~150'. ECT ~, retest 3732 - 3734'. Tool'assembly: 2 outside BT recorders, 4' of 2 7/8" perf'd tail pipe, 7" type "C" hookwall packer, VR safety Joint, hydraulic jars, 2 inside BT recorders, hydrospring tester and dual closed in valve. Ran on 3573' of 3½" DP and 92' of ~" drill collars. Used no water cushion. ~et packer at ~690' with 15' of tail to ~705' at 10:56 A.M. Opened tester at 11:00 A.M. for 5 rains, pressure release. Immed- iate light blow for 5 rains. COMPL~.TION REPORT Se,ction ..25.~. ~.~. !3~ N. ~. R. 10 W., Seward B & M S~~ O~ C~~ OF C~~~, W. O. I. - OPhiR Page 8. Shut in tester at ll:O5 A.M. for 29 mins. ISI pressure period. Opened tool to surface at 11:34 A.M. for 60 mins. flow test. Shut in tool at 12:34 P.M. for 30 mins. FSI pressure. Pulled packer loose at 1:04 P.M. with 42,000~. Dead throughout flow period. Recovered lC' net rise, all rat hole drilling fluid. Pressure data: Bottom inside ' '3678' 19~ 69" 22/25 22/22 42 197~ Top outside 3697' 2019 67 35/40 38/32 43 1995 Bottom outside 3701 2032 79 35/47 35/~4 59 2018 Conclusion: WSO - OK. Schlumberger jet perforated 4 ½" holes per foot 4111 4105' 4078 4068' 4060 - 4056', 4024 - 4020', 4014 - 4008', 3668 - 3650' and 3458 - 3~37'. Ran bit and casing scraper to 4150'. Pulled and ran open ended drill pipe to 4150' Circulated and conditioned mud. De~gember 2.3~ 1962, Picked up and ran 133 0oints 2 3/8", 4.7~, N-80, 8R, EUE~ Rg. 2. TUBING DETAIL - PRODUCTION STRING K. B. DEPTE K. B. to landing flange 14.03' 108 joints 3306.27' 3320.30 2 3/8" Camco sleeve valve 2.70' 3323.00 1 Joint 31. 31' 3354. ~1 2 3/8" Brown CC safety joint · 76' 3355- 07 23/8" X7 Brown HS-16-1 packer 6.00' 3369.07 2 Joints 63.06' 3432.13 2 3/8" Camco D nipple .93' 3433.06 22 Joints 672.20' 4105.26 2 3/8" venturi shoe · 58'_.. ~105.84 tubing landed at 4105' 84' Ran 66 Joints 2 3/8", 4.7~, N-80, 8R ~.2 with turned down couplings. TUBING DETAIL - CI/tO~TING STRING L~ I ' ' ' ' 11 ' ' . , ,#,~ ,, ,, R rL ~ , _ , , , K~ B. to landing flange 66 Joints 2 3/8" tubing tubing hung at 14.03' 2016. ~030· 67I' Removed BOPE and installed and. tested x-mas tree with 5000 psi - OK. CQMPT,W, TION REPORT ~u~ RrCER ~ Section 25~ T. l~ N., R.' lO, ~.~ Se~ ~ & ~ Pa¢ 9. ~~ o~-c~~ o~ c~~~, w. o. ~. - OPEneR ~cem~r 24~ 1~2 Die.ced ~d with oil ~d shut well in. ~cember 25, ,.~962 Well s~t in. December 26, 1962 8et packer at S363' an~ flowed we~. ~cember 27, 1962 ._ Flow tested well. ~d ~fficulties obtai~ng ~sentative flow ~tes due to freezing problems. Representative rates: Bean Size Rate 20/64" December 28. 1962 Shut in pressure 1775~ psi. Rig released at Il:BO P~M., 12-28-6B. T~bing Pressure 7750 MCF/.D 1445~ psi 62oo ~CF/.D 1550~ psi ~.5oo ~CF/,D 16~,~ S. R. NANSEN SRH:pb COMPLETION REPORT Section 25~ T' ,13 N.~. R. 10 W.~ Seward B & M S~t~.IlDgttD OIL COI~AI~ OF CAL]~"OI:INI~ W. O. I. - OI:~i:~TOR DEVIATION DATA . 178 ' 0015 ' 290' 0045 ' 383' 0o30' 683' 0°15 ' 986' 0°45' 1504" 0045' 2110' 0015 ' 2360 ' 0o30 ' 2658' 0~°15 ' 2945' 0~45' 3621' 0015 ' 3808' 0°15 ' 4530' 0015' 5005 ' 0°15 ' 5535' o_°3o' 5800 ' 0° 30 ' ~th Degrees AMERICAN STRATIGRAPHIC COMPANY TRANSMITTAL Mr. Thomas Marshall Petroleum Branch Division of Mines & Minerals .,August, 2,3, 1966 Dear Sir: We have transmitted this date via delivery tO your_ office one set of (washed ) samples from 290 to 5800 from the: Standard Oil Compar~F of Calif. No. 212-25 Beluga River Receipt Acknowledged: Dale W allington American Stratigrapktc Co. ....................... r i '~r. ....... j , T *~ I Il, III - · ~:~_/ PLUGGING RECORD ..--- ~.. Operator - ~ , , ' . ~{~Of %Yell ~-~w~-~ge or ~look ~ ~urvey { County I . , A~lication 'to drill' this well was filed ., H--J this welt ever I Character of well at completion (initial ~roduc~ion): in name of ~ ~ { ~ro~uc~ oil or gas Oil (bbls/day) Gas (MCF/day) Date plugged: Total depth Amount well producing when plugged: Oil (bbls/day) Gas (MCF/day) Water (bbls./day) - Name of ~ch formation con- Fluid conte~t o~ each formation Depth Interval of each fo~atlon Size, kind & depth of ~lugs use~ taining oil or gas. Indicate Indicate zones squeeze cemented, ~hich formation open to well~ ~vlng amount cement. beta at time of plugging . ,,, ,, . - ,, ~ , , , , , i ,, Size pipe Put In well (ft.) Pulled out (ftJ) Left.in well (ft.) Give dep~ a~ Packers and shoes method of parting c~ing (shot, ~ , ~pped etc) . . ~, . ,, ...... _ ~as well flll~ with mud-laden fluid, according to regulations7 Indicate deepest formation containing fresh water. ,, , , , N~ES AND ~D~SSES O~-~JACE~T L~SE OPERATORS OR OWNERS O~ THE SU~AC~ . . . . , Name Address .... Direction from this well: . . . ' ' '' ,, m In ~dition to other information r~uir~ on t~s fo~, if ~is well w~ plugged back for use ~ a fresh ~ater well, give all pertinent de~[ls of ~lugging operations to .base of fresh ~vater sand, perforated interval to .fresh ~ater sand, n~me and address' of surface o~vner, ~nd ~ttaoh letter from surface owner authorizing eompletio~ oi this well as ~-'water well and a~eeing to assume f{ll liability for any subsequent plug- ging ~hieh might be required. ' mm , ~" , Use reverse side for additioual detail File this form k duplicate wi~ the Commission. CER~FICATE: I, the ~dersi~ed, state ~at I ~ th~ ~ of ~e . . ~ %be bes%-o~ ~ ~owle~e. r RECEIVED A__~ .... i a~].~ Si~ature . ~aska Off ~d Gas Conse~aflon Commission Plugg~g ~ecord 19 1963 Form No. ~-15 Author~ed by Order No. 1 ~on o[ Mines and Minerals Effective October 1, 1958. Alaska D~pt. of Natural Resources UNITED STATES DEPARTMENT Of THE INTERIOR GEOLOGICAL SURVEY LESSEE'S MONTHLY REPORT OF OPERATIONS ,State .... Alaska ....... Coz~n. ty ..... ._Qook__In!__e_t_?rea . .~:,,ld .... ~.dcat ..... ~~' , TJ~e follomi~ i.~ a correct report of opcratio;~: ~nd prod~cti,m (iu,:luJin.~ drillin.~' and proJttciitg wells) for thc m on.t/~ o~ . ___ D_~q,gqqr ......... /;: .62 ........... ...................................... ~ho~age~ _~aska slain.,.,/ C. ~. ~ATTE~ .... AND 13N 0W ; 1 Drm~ ~ 5/8"' hole 2364i - 5030'~. R~ 1,gs. . Drillea 9 5/8" hole to ~ ~.D. ~ l~gs' Cemented 7" ca~ing at 57~6' ~ ~h~ee stages with 300 aac~s ~e~nb a~ Sh~, 450 ~acks ~mugh D.V; at 4330' ~ 2~ sac~ through D.V. at 1469'. Drilled ou~D.V, co~s ~ ~esee~ ~th 2OO~ psi - O.K. Clewed ~t~to 5722~. ~covered. 3~'~ net rise. Sli~ ~lugging~ Attested to bre~ d~n hol~s a~ 55~ ~h 46~ psi. ~ Equalized 32 sac~s ce~nt on ~op ~f re~ne~ at 5379:'. Shot 5 - ~" ho~es at 428~'. Brek~ do~ fer~ion at 4280' Broke amp for~tio~ a~~eezed)~h 16~ sacks ce~n~. cement be sRueezea ab 50 sacks ~emen~o I t l ]' · Drilled ~% cement to 52~O'. Sh~ 4 - ~ ~holes per foot 3732' - ~34'.~ ~ HCT ~. Equalized 20[sacks of at ~97'.{ ~led ~d se~ re~ne.~ at 360~'. Squeemea holes at 3732'~ 373~' w~t~ 150 sa~s c,ment~ ~rilled ou5 ~e~,% to So'.l Squgezed hole~ st 3h20 with ~O,'sacks Ceme,~o Dri~ed ~at ce~nt ~ rdt~r a'. 365~.t. Ran / I j contin}ed ....... .. '~ petroleum t ) ~~.~a an5 Minerals Au~ka Dept. of lqaturoi Resourcel No?~..--There were ...................................... run.s or sales of oil; ................................... '1~ cu. fi. of gas sold; ............................................. runs or sal(~s of gasoline during the mouth. (Write "no" ~vhere. apptical~le.) No~}:.---Iteport on thkq iorm is required for each calendar month, regardless of the stat us of operation~, and mush be filed duplicate wi[h the supervi~r by the 6th of tho s, meeeding month, unless o[herw~e directed by thc supervisor. (Jau~y 19~0) UNITED STATES DEPARTMENT OF THE INTERIOR GEOLOGICAL SURV'EY LESSEE'S MONTHLY RE?O'RT OF OPERATIONS State .................................. County ................................. t,¥~'~d ...................... Tt~e followin.~ i.~ a c. orreot, reportJ of opcration,~? 6:n.d prodt, ctb~z~ fD~,cludi~qy driliin,..i~, and pr.,{D:ein~ wells)/'or thc n?.o,,_.th o/. ................................ '9 ........................ .~en,~'s addre.~.,~ .................................. Compa ,~,':/ .......... .................................................. Si~'n. cd .... Pl~one ............................................................................... ~l~e~;t's titi~ . ................... ~-~ o~' ~,~ TwP. ltA~'{;~, W?;I, LNo. 2012 ' · Removed ~ oil. Sef Well shut 2~no Rig released D U.S.G.S. State RlchfielC 8hell Files ecember 28 - M. H. Soyster o R. Marshall - C. W. Pe~ry Re R. Ritter . R. ,~obison roduc ~ng xplor tion I 1962. ' - 4105', 4078' - - 4008', 3668' - ctrc?lating string at ! tree o Dksplaced mtui w~th d well c Lean° I ! e. ,.L '., .'., ' { Division of Noum.--There were ...................................... runs or s~des of oil; .................................... M cu. ft. of gas sold; .............................................. runs Or sales o~ gasoline during the month. ('Write ~no" where al>pi{cable.) No~.--}~epo~ on this form is mquked for each calendar men,h, rega. rdlcss of ~ho skdus of oi)6ra[ioua, and llltl$~ be flied iu duplicate with tho supervisor by the 6th of the suco~ding month, unless otherwise di~cted by tho supervi-'or. (Jan~y 1~) UNITED STATES DEPARTMENT OF THE INTERIOR LESSEE'S MONTHLY REPORT OF OPERATIONS Budget itu:eau No..!~ [C~5~.~.. Approwi oxpim~ 1~-~1~0. Lm~O OVFI'. ~ ..~chorage GEOLOGICAL SURVEY u~ ............~oho~ge ~.~ Th.e followinff is a correct report of overalions a.d prodac~io.. (incl~dinff drilling and producir~ d~e~t's address P, 0~ Box 7-83~ Compa..~A~~ 0IL C0. ~ O~. W,0,I, .................................... ~ OF ~ TWP. [~ANG~ o~ u- ~,, ' ~,,-- ~ ~ ........ = ......... ~.. ' ..... S~dded ~vemb~r 13, 19620 gr~led 20" h(}le to 290'. Ce~nt~ 16" oasi~ at 288' ~th 300 sacks,, ce~nt~ Dr~led ~ 3/4" Dri~e~ hole to ~17~. ~ log~. ~ 3/4'[ hole to 2123' ~ logs~i Dri~ed ~ '3/h~ hole t 2364'. R~ logs. C~nged 10 3/4" ~asi~ at 2364' ~th 9%0 ~acks ce~ent~ U.S oG .S. State - T Richfield Shell - R File s P L { - Mo ~. Soyster · R. garshall - C. I W. Perry o R. ~bison ~lor~tion i No,-. There were ....................................... rurm or sales of oil; ................................................ M cu. ft. of gas sold; ............................................. runs or sal.s of gasoline during the month. (Write "no" where applicable.) No.v..--Report on this form is required for each calendar month, regardless of thc status of operations, and must be filed in duplicate with the supervisor by ~he 0th of the succeodiug mouth, unless otherwise directed by the supervisor. Forth 9-329 (JSllllal~ 1~0) 10--215700-'8 ti. ~. OOV~'RWWlV:NT ~'nl~rlNo OFFICg ON :WELi~ UNI!ID STATIt DEPARTMENi? OF TH~ INTERIOR ~xx.o~lcAI. SURVEY SUNDRY NOTICF.~ AND REPORT8 ON WELI~ ~1c~ o~ ~r~mo~ TO S~OT O~ ~;:~ZE ......... L (INDICATE ~ ~y ~ lilAiIK NAllJRE QIr RIII~OIIT. IIIOTI(~ t~l ~ DATA) m,mmmkmmdHkumMmmdv,.~mmim~MIW.~i~.qk.~..~~~b~ .~. ~ -~," "-;'-'-Z.r~. ~' '-T '~ ....... '.,.~ :' ;' 'k ',- ';:~'"' "' :~' -.*' ," ' -., ,'"~' "-' -' " ~ ' ~'_/ I i . ,-.:' '-_ .... :-::.-.~./_ z.~ 1._ ' . Division of Mines an~ Minerals Mr. Orin Gilbert of Standard, Producing Department, called regarding trouble with the Beluga River Unit 212-25, a gas well they are drilling. He had dis- cussed the large pipe they were going to use with you previously but they ~ant approval of the following changes: they will drill 5~" casing in the gas well, drilling to 200 feet and set 16" casing at 200 feet. Will install BOPE and drill to 2200 feet. They will cement 10 3/4 casing at 2200 feet with 1250 sacks. They they will install BO?E (Class 4) and then drill'out and drill ahead to 6000 ft. They will run logs at 2200 feet and at ~xxH~ 6000 feet. They will run a combination (?) string, 7" and 5~". 2150 ft. of 7" and 3850' of 5~" which will extend to 6000 feet. This will be done in 3 stages. Two DV collars. They want to run (heater or hotter?) string up above and will go into that when he talks to you. He needs approval because they are changing the entire program, running 4 strings of tubing and testing again. This will be a Revised Beluga River Unit 212-25. In addition they will perforate, test and complete between about 5000 and 5500. Mr. Gilbert advised that the well was spudded today on morning tower so approval should be obtained as soon as possible. His office phone is BR 76201, however if you'd like, you could call him at his home, FA 24713. (,$'UBMIT IN TRIPLICAT~J UNITED STATES DEPARTMENT OF THE INTERIOR G£O-O~,CA- SUnV~ NOI/ $ 1962 SUNDRY NOTICES AND REPORTS '° I I (INDI~ATIE A~OVE BY CHECK MARK 1,4ATL/I~W O4r I~EP'~T. NOTICe. O~ OTHB:~ DATA) Wdl No. _._BgU._.__.2_.l.2._-_.25[s lo~ated 2015 _~t. from__ ~} line anci 5~5 _.ft. from ~} line of sec ..... ~._~._.~__~__ S_ ~_,_ ~_25_ ....... _?..__ii.__., ......... _~. ~___W ........... S~r_d____a ~.._1~ (~ See. aaa 8~. No.) CTwp.) 0~ap) (Maqdi~) .......... _.B~.__I. _Ug.a._ _ _ _~Y_e~_ ........ K. B. Thc .i~v~tio. of th¢lffi~ail:illi~ ~5o~ ~e~ 1¢v¢1 i~ _~_~__~_. ft. , DETAILS OF WORK: ~t~ ~ off .nd o~t~d d~p~ to ~bj~l~ ~s~l~l ~w Mm, ~t*~ ~t~m d ~ ~--1 i~1~o ms~Kdt~ ~ 1. Drill to 200' and cement 22" conductor pipe. 2. Install 22" Clams III Bleweut Prevention Equipmen[ and test before drilling out. 3. Drill to 2200' run logs and cement 16" casing at 2200' (Cement to surface). 4. Install Class IV Blowout Prevention Equipment and test ~e~ore drilling out. 5. Drill to 6000,. a. Reduce hole sime at ~2950 and drill _+100'. Run logs and if warranted run op~n hole formation t~l~. bo Open hole and d~i~l to 6000' and run logs. 6o Cement 10 3/4" casing a~ 6000~. ?. In, tall Class IV Bluest Preventiea Equipment 8. Establish WgO's, perforage attractive intervals and complete as a gas wello Company ....... _._ST_A_._I~__~_ _ ..o_ .I~.._..co .I~.~_ __ .~.. ¢_!~..._~___O__.P~ ...IA~j._._~.e..s..t_.e_.c._n.__.c~_ e. ?_ ~ i 0...~_ ~ ~.__~ ~ ............. '~C. V. .TEtTTF, RTON' / Title D_i..s _t r i c ~ _ Sup.e. ri..n._te ~_d..~.p._t_ ...... m 13N. R, IOW. I T. 12 1 I S.P.N. · R.iO~ 4 22 27 - -- I I~l- I III I I ,~JJr i L i I · J i i I 26. Co ,RO Co -f- -4- PROP0'S£D · LOCATI~:; RELL 212-25 - &. ozg658-.i ~Vell location ~. _ . (give footage from section lines) ' Section--township--range or block & survey Distance, in miles, and direction from nearest town or post office Nearest distance from proposed loc~tion ' to property or lease line: feet Distance from proposed location to nearest drilling, completed or applied for well on the same lease: feet Proposed depth:: ~ fil Rotary or cable~tools Nmnber of acres in l~!/' '~[lililb~ - Approx. date work will starl Number of wells on lease, including this well, completed in or drilling to this reservoir: If lease, purchased with one or more v-ells drilled, from whom purchased: Name '-: Address Status of bond Remarks: (If this is an application to deepen or plug back, briefly describe work to be done, giving present producing zone and expected new producing zone) CERTIFICATE: I,. the .undersigned, state that I am .the , : , of the (company), and that I am authorized by said company to make, this report; and that this report was pre. pared under my supervision and direction and that the facts stated therein are true, correct and complete to the best of; my knOwledge, Permit Number:, 33 . Appr°val Da'e: ~ ' ' ~, Ap.roved By: ~ Notice: Before sending in this form be sure that you have given all information requested. Much unnecessary correspond- ence win thus be avoided. See Instruction on Reverse Side of Form Alaska Oil .and Gas Conservation Commission . Application to Drill, Deepen or Plug Back Form No. P-1 Authorized by Order No. I Effective October 1, 1958 ftandard Oil L ~ of California Pe ..,,it. No.: 33-62 Beluga River Unit No. 212-25 Issued: 11-5-62 Loc: 2015' FNL & 595' FWL Sec° 25, T13N-R~W, SB&M Elev: 42' KB 27' Grd. Contr: Coastal Drilling Company Spud: 11-13-62 Comp. GSI 12-28-62 ToDo 5,800' I.P. 7750 MCF/D. 28/64" Bean. To Po 1445 psi. Csg: 36" C 29'~'- 16" C 288' w/ 300 sx.;- 10 3/4" C 2364' w/ 950 sx. 7" C 5776' w/ 300 sx @ shoe & 200 sx @ DVC 4327' Plugs: 4150'-4204" Retainer @ 4204" 4250'-4280'; 5220'-5379'~ Retainer @ 5379'~ 5722'-5776'. Perf: 5h @ 3420' (squeezed 4/ft. 3~ '-34' (squeezed) 4/ft. 42Z~6'-48' cmtd. off 4h @ 4280' (squeezed & cmtd. off) 5h @ 5506' cmt~. ~ff. 4/ft. 3437'-58 , 3650'-68' 4008'-14' 4020'-24' 4056'-60' 4068 ' -78 ' 4105 ' -11 '
