The URL can be used to link to this page

Home My WebLink About169-0951. Operations Susp Well Insp Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Install Whipstock Perforate Other Stimulate Alter Casing Change Approved Program Mod Artificial Lift Perforate New Pool Repair Well Coiled Tubing Ops Other: Replaced ESP Development Exploratory Stratigraphic Service 6. API Number: 7. Property Designation (Lease Number): 8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071): 10. Field/Pool(s): 11. Present Well Condition Summary: Total Depth measured 10,506 feet N/A feet true vertical 10,029 feet See schematic feet Effective Depth measured 9,969 feet See schematic feet true vertical 9,521 feet See schematic feet Perforation depth Measured depth 9,370 - 10,260 feet True Vertical depth 8,955 - 9,796 feet Tubing (size, grade, measured and true vertical depth) 2-7/8" L-80 9,138 (MD) 8,735 (TVD) Packers and SSSV (type, measured and true vertical depth) See schematic 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13a. Prior to well operation: Subsequent to operation: 13b. Pools active after work:Hemlock Oil & Middle Kenai G Oil 15. Well Class after work: Daily Report of Well Operations Exploratory Development Service Stratigraphic Copies of Logs and Surveys Run 16. Well Status after work: Oil Gas WDSPL Electronic Fracture Stimulation Data GSTOR GINJ SUSP SPLUG Sundry Number or N/A if C.O. Exempt: Authorized Name and Digital Signature with Date: Contact Name: Contact Email: Authorized Title:Contact Phone: 3,090psi 4,790psi 3,090psi 5,750psi 6,890psi 3,006 2,905 Burst Collapse 1,540psi measured TVD Production Liner 9,674 9,467 1,017 Casing Structural 9,242 9,047 7" 9,674 9,467 10,480 1,003 400 3,006 400Conductor Surface Intermediate 33" 13-3/8" 9-5/8" 8,160psi 7-5/8" STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 169-095 50-733-20203-00-00 3. Address: Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 N/A 5. Permit to Drill Number:2. Operator Name 4. Well Class Before Work: ADL0018729 McArthur River / Hemlock Oil & Middle Kenai G Oil Trading Bay Unit D-20 Plugs Junk measured Length measured true vertical Packer Representative Daily Average Production or Injection Data Casing Pressure Tubing Pressure 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 113 Gas-Mcf MD N/A 972 Size 399 1705 10428 48 125952 103 324-690 Sr Pet Eng: 7,020psi Sr Pet Geo: Sr Res Eng: WINJ WAG 16 Water-BblOil-Bbl 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Casey Morse Casey.Morse@hilcorp.com 907 777-8322Operations Manager N/A Form 10-404 Revised 10/2022 Due Within 30 days of Operations Submit in PDF format to aogcc.permitting@alaska.gov By Gavin Gluyas at 9:30 am, Feb 18, 2025 Digitally signed by Dan Marlowe (1267) DN: cn=Dan Marlowe (1267) Date: 2025.02.17 12:15:13 - 09'00' Dan Marlowe (1267) DSR-2/18/25 RBDMS JSB 021925 BJM 4/14/25 Updated by: JLL 01/28/25 SCHEMATIC Trading Bay Unit Well: D-20 PTD: 169-095 API: 50-733-20203-00 Completed: 01/15/25 PBTD = 10,430’ TD = 10,506’ MAX HOLE ANGLE = 21q, @ 2100’ RKB to TBG Head = 41.8’ 11 HK-1 HK-4 HK-5 HK-6 12 HK-3 Fill tagged on 8/26/88 @ 10,201’ No Joy on 2-1/16” tbg thru pkr. during WO in 11/83 Csg Shoe @ 9660’ DIL Tagged 9,969 SLM 1/9/25 G-2 G-4 G-5 DV Collar 5,204’ 10 1-9 A CBL Good BondFrom 8450’ to 9450’CBL Good BondFrom 9960’ to 10,400’CBL Good Bond9663’ to 9669’9677’ to 9680’9744’ to 9749’ Brief Details & Info: To date Spudded D-20 on 9/20/69. TD @ 10,506’ on 10/25/69. Completed & RR on 11/06/69. x Hole Section MWT:x Approximate Rotating hrs: o 17-1/2” to 3050’ 9.9 to 10 ppg o 33” 60 hrs o 12-1/4” to 9,748’ 9.8 to 10 ppg o 13-3/8” 285 hrs o 8-1/2” to 10,506 o 9-5/8” 51 hrs o 7” 16 hrs A 4/29/75 D-27 collided w/ D-20 while drilling 17-1/2” surface hole.Communication to Inlet. Spotted 500sx of G cmt @ 400’ in D-27. Possible length of breach in 13-3/8” is 1488’ to 1497’. Penetration in D-20 9-5/8” @ 1497’. 7/75 WO sqz’d 9-5/8” csg @ 1497’ 4x. Total cmt placed 650 sx. JEWELRY DETAIL NO Depth (MD)Depth (TVD)ID OD Item 41.80’ 41.80’ 2.992” 11.000” Tubing hanger: FMC-TC-ESP, 11”x3-1/2” IBT lift & susp, 300-4 seal pocket, w/ 3" Type 'H' BPV profile, 2- 3/8" CCL, alloy material 10 9,044’ 8,646’ - 5.130” Bolt on Discharge 9,046’ 8,648’ - 5.380” Pump (X2) 538 Series, 114 & 076 Stage, SJ2800 9,085’ 8,685’ - 5.130” Intake, Sub-Assy A/R-X2, 513X, 416 SS, Inconel Shaft 9,087 8,687’ - 5.130” Upper/Lower Tandem Seals, 513 Series BPBSBPB 9,110’ 8,708’ - 5.620” Motor: 562 Series, KMS2, 360HP/3175V/70A 9,137’8,734’ - 5.620” Centralizer / Anode 11 10,068’ 9,615’ 3.250 Baker Model “D” Pkr. 10,078’ 9,624’ 2.750 Otis “X” Nipple, size 2.75 10,086’ 9,632’ 3.000 Bell Guide 12 10,198’ 9,737’ 3.250 Baker Model “D” Pkr. 10,206’ 9,745’ 2.625 Otis “Q” Nipple, size 2.625 10,212’ 9,750’ 3.000 Mule Shoe CASING DETAIL SIZE TYPE WT GRADE CONN ID TOP BTM. 33” Conductor Surf 400’ 13-3/8” Surf Csg 61 K-55 Seal Lock 12.515 Surf 3,006’ 9-5/8” Prod Csg 40 N-80 Butt 8.835 Surf 4,390’ 43.5 N-80 Butt 8.755 4,390’ 6,156’ 47 S-95 Butt 8.681 6,156’ 7,080’ AR-95 Seal Lock 7,080’ 9,674’ 7-5/8” Tie-Back 29.7 L-80 SLIJ-II 6.875 Surf 9,467’ 7" Liner 29 N-80 X-Line 6.185 9,463’ 10,480’ TUBING DETAIL 2-7/8” 6.5 L-80 8RD 2.441 Surf 9,138’ PERFORATION DETAIL Zone Top (MD) Btm(MD) Top (TVD)Btm (TVD) Amt. SPF Last Perf Date Present Condition G-2 9,370' 9,388' 8,955' 8,972' 18' 5 03/19/2015 Open G-2 9,421’ 9,445’ 9,004’ 9,026’ 24’ 6 03/29/2017 G-4 9,478' 9,484' 9,057' 9,063' 6' 5 03/19/2015 Open G-5 9,610’ 9,627’ 9,182’ 9,198’ 17 5 03/19/2015 Open Sqz 9,680' 9,681' 9,248' 9,249' 1' 4 11/02/1969 Sqz 100 sx cmt. Sqz 9,750' 9,751' 9,315' 9,315' 1' 4 10/30/1969 Sqz 75 sx cmt. HK-1 9,820' 9,885' 9,381' 9,442' 65' 20 06/15/1992 Open f/ Production HK-1 9,828' 9,862' 9,388' 9,420' 34' 5 03/19/2015 Open HK-3 9,905' 9,950' 9,461' 9,503' 45' 16 06/15/1992 Open f/ Production HK-4 9,908' 9,932' 9,464' 9,486' 24' 5 03/19/2015 Open HK-4 9,950' 10,065' 9,503' 9,611' 115' 16 06/15/1992 Open f/ Production HK-4 9,964' 9,986' 9,516' 9,537' 22' 5 03/19/2015 Open HK-5 10,070' 10,190' 9,616' 9,730' 120' 16 Jul-75 Open f/ Production HK-6 10,230' 10,260' 9,767' 9,796' 30' 4 Jul-75 Open f/ Production GAS LIFT MANDRELS STA MD TVD ID Type Port Valve Psc Date 1 2,283’2,229’ 2.441 GLM #1: 2 7/8” PSPO-1M 16 Dummy 01/13/25 2 4,252’ 4,083’ 2.441 GLM #2: 2 7/8” PSPO-1M 16 Dummy 01/13/25 3 5,565’ 5,337’ 2.441 GLM #3: 2 7/8” PSPO-1M 20 Dummy 01/13/25 4 6,300’ 6,034’ 2.441 GLM #4: 2 7/8” PSPO-1M Dummy 01/13/25 5 6,776’ 6,492’ 2.441 GLM #5: 2 7/8” PSPO-1M 20 Dummy 01/13/25 6 7,315’ 6,999’ 2.441 GLM #6: 2 7/8” PSPO-1M Dummy 01/13/25 7 7,854’ 7,508’ 2.441 GLM #7: 2 7/8” PSPO-1M 20 Dummy 01/13/25 8 8,328’ 7,961’ 2.441 GLM #8: 2-7/8IN, SLIMHOLE 24 Orifice 01/13/25 9 8,997’ 8,602’ 2.441 GLM #9: 2 7/8” PSPO-1M Dummy 01/13/25 Page 1/2 Well Name: MRF D-20 Report Printed: 2/4/2025WellViewAdmin@hilcorp.com Alaska Weekly Report - Operations Jobs Actual Start Date:12/24/2024 End Date: Report Number 1 Report Start Date 12/31/2024 Report End Date 1/1/2025 Last 24hr Summary Load carrier, A-leg, DW & beam package on boat. Transfer from Bruce to Dolly Varden. Offload beam package and center onto D-20. Install carrier, A-leg and mast. Secure all in place. Release Titan for second round equipment transfer from Bruce. Report Number 2 Report Start Date 1/1/2025 Report End Date 1/2/2025 Last 24hr Summary Continue rig up of 404. Stand mast and spool on lines. Second boat arrived, offload equipment and spot. Rig up pump, tanks and circulating system. Tie in bang board electrical. Report Number 3 Report Start Date 1/2/2025 Report End Date 1/3/2025 Last 24hr Summary Complete move in of equipment. Pumped a total of 1730 bbl of FIW down the tbg and recovered 310 bbls of returns to production. Tbg volume, IA volume and volume below ESP pump bullhead/circulated out as per Sundry. ND tree and NU BOPE. Stand rig and install floor. Preparing for BOPE testing. Report Number 4 Report Start Date 1/3/2025 Report End Date 1/4/2025 Last 24hr Summary Complete RU. Complete BOPE testing 2-7/8'' & 3-1/2'' to 250/2500 psi for 5/5 min as per AOGCC and Hilcorp expectations. Witness waived by Jim Regg on 01/2/2025. Remove blanking sub and TWC. Report Number 5 Report Start Date 1/4/2025 Report End Date 1/5/2025 Last 24hr Summary Well on vac. Pull TWC, MU landing joint, back out lock downs, pull hanger. Hanger off seat at 110k, pulled up to 158k then broke over and pulled at 148k. With hanger off seat, pump 100bbl FIW down IA. Pull hanger to rig floor, disconnect ESP cable and chem lines. RU ESP cable sheave and run cable and lines through to spool. LD landing joint and hanger. Hold bare pipe shut in drill. POOH f/9150' t/2599' w/ 3.5" 9.2# L-80 SuperMax, ESP/GL completion laying down singles. Filling hole 20BPH. Report Number 6 Report Start Date 1/5/2025 Report End Date 1/6/2025 Last 24hr Summary Cont. POOH f/2599' t/129' w/ 3.5" SM ESP/GL completion laying down singles (266 total joints and 9 gas lifts). RU Summit handling equipment and LD ESP. ESP overall in good condition, appears to be a cable failure on the well. Work boat, crane brakes not holding, mechanic got crane brakes working. Boat needs to wait on tide to complete offload. P/u BHA handling equipment. Make up cleanout BHA #1 w/ 5.5" tri-cone bit. Cont. to offload boat and lay out 385 joints of 3-1/2" PH 6 and five 4-3/4" collars. Backload remaining completion tubing. M/u remainder of BHA#1 consisting of 4 drill collars and XO back to 3-1/2" PH 6. Change out handling equipment for p/u work string. Single in hole w/ 5.5" tri-cone bit cleanout BHA #1 on 3-1/2" PH 6 work string. Filling hole with 20 bbls FIW/hr. Report Number 7 Report Start Date 1/6/2025 Report End Date 1/7/2025 Last 24hr Summary Single in hole w/BHA #1 on 3-1/2" PH 6 workstring to f/622 t/6,720'. P/u power swivel from power unit and chain it back in the derrick. Cont single in hole w/BHA #1 on work string to f/6720' t/9206'. Pump 25 bbl salt pill chased w/ 68bbls FIW. Cont single in hole w/BHA #1 on work string to f/9206' t/9895'. P/u wt. 134k, s/o wt. 94k. Top filling well w/ FIW continuously, trying to top off well after pumping salt pill. Unable to load pipe on beaver slide due to wind. Housekeeping and organizing while waiting on wind to die down. Report Number 8 Report Start Date 1/7/2025 Report End Date 1/8/2025 Last 24hr Summary Continue to wait on wind. Pump 30BBL salt pill down the tubing and chase with 100BBL FIW. Cont single in hole w/BHA #1 on workstring f/9,895' tagging at 9,988ft. Top off well w/100bbls FIW. Pick up power swivel. Install stripping head. Reverse circulate, returns caught at 154bbl pumped. 1.5BPM losses while circulating at 3.5BPM. Wash in hole from 9,988' to 10,000' (jt 316 down), lose returns. Pick up full joint and wait for returns. Fan blade on the rig broke and went through the radiator. Swap pump to fwd circulating, pipe plugged off, surge up to 2,000psi, power swivel leaking. SD, secure well. Pull fan and radiator. Go through pump fluid ends, found some worn valves, replace valves. Received radiator and fan. Install fan and radiator. Mix 58bbls salt pill. Pressure up on tubing to 2500psi and work pipe and surge pressure trying to free obstruction while building pill. No luck. Pump 35 bbl salt pill chased with FIW. Report Number 9 Report Start Date 1/8/2025 Report End Date 1/9/2025 Last 24hr Summary Chase pill down IA, pressure up to 1,000psi on the IA. Try to work plug out of pipe, no luck. POOH wet f/9,988' t/ 6,435' racking back 3.5" work string. RU Pollard SL. RIH tag and set stop at 5,965' SLM. RIH and attempt punch, no joy. Rebuild tubing punch, RIH w/ punch #2,, tubing punch did not fire, RD SL. Cont POOH wet f/6,435 t/1903' racking back 3.5" work string. Maxed out derrick with 130 stands. Cont POOH l/d singles wet f/1903' t/148' (56 joints) 3.5" work string. All work string pipe clear of solids, 2.25" bait sub and 2.5" GR on top of BHA XO. L/d BHA #1. Attempt to knock solids from components. First collar was clear, remaining BHA was packed with sand. Clean floor. R/u slick line to run bailer. Report Number 10 Report Start Date 1/9/2025 Report End Date 1/10/2025 Last 24hr Summary RIH w/ 3" bailer, tag at 9,969' SLM, POOH. Small scale sample in bailer. RD SL. MU BHA#2 6-5/8" tri-cone bit, 7-5/8" casing scraper & jars. RIH on 3.5" work string out of the derrick t/ 8,115'. Single in hole f/ 8,115'-t/9,339', P/u wt. Reverse circulate 1.5 BU FIW at 3.5 BPM, 400psi w/ a loss rate of 8 BPH. Did not see any solids come across the shaker. L/d top single, POOH w/ BHA #2 racking back 3-1/2" work string f/9339'-t/29'. Break down and lay down scraper BHA #2. Clear floor of unneeded handling equipment and tools. Field: McArthur River Field Sundry #: 324-690 State: ALASKA Rig/Service: 404Permit to Drill (PTD) #:169095Permit to Drill (PTD) #:169095 Wellbore API/UWI:50733202030000 , pipe plugged off, surge up to 2,000psi pp g Cont single in hole w/BHA #1 on workstring f/9,895' tagging at 9,988ft. Top off well w/100bbls FIW. Pick up power swivel. Install stripping head. Reverse circulate,gg,ggg,ppp returns caught at 154bbl pumped. 1.5BPM losses while circulating at 3.5BPM. Wash in hole from 9,988' to 10,000' (jt 316 down),(j ) ,p Single in hole f/ 8,115'-t/9,339 Page 2/2 Well Name: MRF D-20 Report Printed: 2/4/2025WellViewAdmin@hilcorp.com Alaska Weekly Report - Operations Report Number 11 Report Start Date 1/10/2025 Report End Date 1/11/2025 Last 24hr Summary MU tripoint 7-5/8" test packer. RIH on 3.5" work string t/ 9,320'. Set test packer at 9,320ft, fluid pack the IA with 40bbl FIW. MIT casing to 2,250psi for 30min charted, good test. Release packer and POOH LD singles f/9,320' to packer. LD packer. M/u 2-7/8" test joint, run in test joint w/ test plug. Fluid pack BOPE, purge air. Pressure up to 2500psi and look for leaks. Report Number 12 Report Start Date 1/11/2025 Report End Date 1/12/2025 Last 24hr Summary Test BOPE per Hilcorp and AOGCC standards to 250/2500psi. Witness waived by AOGCC Jim Regg. No fail/passes. R/d test equipment. Offload completion from boat and tally. Single in hole w/ 2-7/8" 8RD tubing to 8806'. POOH standing back 2-7/8" EUE f/ 8806' to surface (133 stands). PJSM w/ Summit ESP crew. R/u Summit equipment. Report Number 13 Report Start Date 1/12/2025 Report End Date 1/13/2025 Last 24hr Summary Assemble Summit ESP, tie in 3/8" chem injection line and pressure test to 2500psi, test cable. RIH w/ ESP/GL completion per tally on 2.875"8RD. Ran pump to 3431', unable to continue due to high winds making stands in derrick unstable for derrickman to latch in elevators. Organize and clean while waiting on wind to die down. Report Number 14 Report Start Date 1/13/2025 Report End Date 1/14/2025 Last 24hr Summary Cont RIH w/ ESP/GL completion per tally on 2.875", L-80, 6.5#, 8RD tubing, f/3,431' t/6,521' checking cable every 1000'. adding 15BBL FIW/hr. Change reels and splice ESP cable. Splice clamp landed out at 6635' (joint 196). Cont RIH w/ ESP/GL completion, f/6,521' t/9090'. M/u hanger and landing joint. Orientate hanger. Terminate motor lead and cap string. M/u penetrator and run through hanger. Run cap line through hanger. Land hanger (60k down), placing bottom of ESP at 9,137.73'. RILD. Last test on cable, good test. back out and l/d landing joint. Install TWC. R/d summit equipment. Prep to skid rig. Report Number 15 Report Start Date 1/14/2025 Report End Date 1/15/2025 Last 24hr Summary Remove rig floor, scope down and lay over derrick, unhook accumulator and circulating lines. RD aux equipment and RU skidding jacks. Skid rig back. Set up jacks on top of single and double beams and skid rig to D-16RD well center. Nipple down D-16RD tree, prep wellhead M/u xo and test sub on hanger. N/d BOP from D- 20. Test penetrator on D-20, good test. Report Number 16 Report Start Date 1/15/2025 Report End Date 1/16/2025 Last 24hr Summary Prep Wellhead, N/U tree, test void t/5k good, Test tree t/250/5000 good. Pull TWC, turn well over to production. Report Number 17 Report Start Date 1/28/2025 Report End Date 1/29/2025 Last 24hr Summary Perform no flow test with Sean Sullivan (AOGCC) witness. Received verbal approval of passing no flow test and returned the well to production. Field: McArthur River Field Sundry #: 324-690 State: ALASKA Rig/Service: 404 IT casing to 2,250psi for 30minp charted, good test. g gj g and hanger (60k down), placing bottom of ESP at 9,137.73'. Received verbal approval of passing no flow test and returned the well to production. Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www.aogcc.alaska.govFebruary 10, 2025 Mr. Dan Marlowe Operations Manager – CI Offshore Hilcorp Alaska, LLC P.O. Box 244027 Anchorage, AK 99524-4027 RE: No-Flow Verification Trading Bay Unit D-20 PTD 1690950 Dear Mr. Marlowe: On January 28, 2025, an Alaska Oil and Gas Conservation Commission (AOGCC) Petroleum Inspector witnessed a no-flow test of Trading Bay Unit D-20 located on the Dolly Varden Platform in Cook Inlet. The AOGCC Inspector confirmed that the proper test equipment was rigged up prior to the test as outlined in AOGCC Industry Guidance Bulletin 21-001. The test procedure employed was a 3-hour shut in period to monitor pressure build up followed by a short pressure discharge through the test equipment. Pressure in the tubing and tubing-casing annulus bled to zero psi within 5 minutes after opening the well to atmosphere. Trading Bay Unit D-20 may be produced without a subsurface safety valve as confirmed by the AOGCC Inspector at the conclusion the test. A fail-safe automatic surface safety valve system capable of preventing uncontrolled flow must be maintained in proper working condition in this well as required in 20 AAC 25.265. The subsurface safety valve must be returned to service if Trading Bay Unit D-20 demonstrates an ability to flow unassisted to surface. Any cleanout, perforating or other stimulation work in this well will necessitate a subsequent no-flow test. Please retain a copy of this letter on the Dolly Varden Platform. Sincerely, James B. Regg Petroleum Inspection Supervisor ecc: P. Brooks AOGCC Inspectors James B. Regg Digitally signed by James B. Regg Date: 2025.02.11 17:16:11 -09'00' 2025-0128_No-Flow_TBU_D-20_ss Page 1 of 2 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg DATE: 1-28-2025 P. I. Supervisor FROM: Sully Sullivan SUBJECT: No Flow Test Petroleum Inspector Trading Bay Unit D-20 Hilcorp Alaska LLC PTD 1690950; Sundry 324-690 1-28-2025: Traveled to the Dolly Varden Platform to witness the no-flow test on well D- 20 post rig workover. The well has been open to atmosphere for 62 hours prior to testing due to weather delaying travel. The tubing and IA were in communication with a 1-inch hose manifold. There were calibrated gauges on the tubing and IA. The Operator chose to use the pressure discharge method. The following table shows test details: Time Pressures1 Remarks Tubing IA OA 0645 0 0 380 Well SI for 3 hr pressure build 0700 0.02 0.01 380 0715 0.08 0.01 380 0730 0.11 0.01 380 0745 0.18 0 380 0800 0.21 0 380 0815 0.26 0 380 0830 0.31 0 380 0845 0.35 0 380 0900 0.38 0 380 0915 0.44 0 380 0930 0.50 0.01 380 0945 0.52 0.01 380 1000 0.55 0.01 380 1015 0.57 0.01 380 1016 0.22 0 380 Well opened to atmosphere 1017 0.19 0 380 1018 0.14 0 380 1019 0.09 0 380 1020 0.05 0 380 1 Pressures are T/IA/OA 2 Gas flow not to exceed 900 scf/hr; Liquid flow not to exceed 6.3 gal/hr Attachments: Photos 9 9 9 9 9 9 99 9 9 99 9 9 James B. Regg Digitally signed by James B. Regg Date: 2025.02.07 14:22:00 -09'00' 2025-0128_No-Flow_TBU_D-20_ss Page 2 of 2 No-Flow Test – TBU D-20 (PTD 1690950) Photos by AOGCC Inspector S. Sullivan 1/28/2025 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 2.Operator Name: 4.Current Well Class:5.Permit to Drill Number: Exploratory Development 3.Address:Stratigraphic Service 6. API Number: 7. If perforating:8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Yes No 9.Property Designation (Lease Number):10.Field: 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: Junk (MD): 10,506 See schematic Casing Collapse Structural Conductor Surface 1,540psi Intermediate 3,090psi Production 4,790psi Liner 7,020psi Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): 12. Attachments: Proposal Summary Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory Stratigraphic Development Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: OIL WINJ WDSPL Suspended 16.Verbal Approval: Date: GAS WAG GSTOR SPLUG AOGCC Representative: GINJ Op Shutdown Abandoned Contact Name: Ryan Rupert Contact Email:Ryan.Rupert@hilcorp.com Contact Phone:(907) 777-8503 Authorized Title: Conditions of approval: Notify AOGCC so that a representative may witness Sundry Number: Plug Integrity BOP Test Mechanical Integrity Test Location Clearance Other Conditions of Approval: Post Initial Injection MIT Req'd? Yes No APPROVED BY Approved by: COMMISSIONER THE AOGCC Date: Comm. Comm. Sr Pet Eng Sr Pet Geo Sr Res Eng CO 228A Other: Replace ESP 1/2/2025 10,480'1,017' 3-1/2" 1,003' Baker Mod D Packers & N/A 10,068 (MD) 9,615 (TVD) / 10,198 (MD) 9,737 (TVD) & N/A 9,467' Perforation Depth MD (ft): 9,674' 9,370 - 10,260 9,467' 7" 8,955 - 9,796 9,047'7-5/8" 33" 13-3/8" 400' 9-5/8"9,674' 3,006' MD 5,750psi 3,090psi 399' 2,905' 9,242' 400' 3,006' Length Size Proposed Pools: L-80 TVD Burst 9,055 6,890psi STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 ADL0018729 169-095 3800 Centerpoint Drive, Suite 1400, Anchorage, AK 99503 50-733-20203-00-00 Hilcorp Alaska, LLC Trading Bay Unit D-20 AOGCC USE ONLY 8,160psi Tubing Grade: Tubing MD (ft):Perforation Depth TVD (ft): Operations Manager Subsequent Form Required: Suspension Expiration Date: Will perfs require a spacing exception due to property boundaries? Current Pools: MPSP (psi): Plugs (MD): 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name and Digital Signature with Date: Tubing Size: PRESENT WELL CONDITION SUMMARY McArthur River Hemlock Oil & Middle Kenai G Oil Same 10,029 10,046 9,593 1,590psi N/A No Form 10-403 Revised 06/2023 Approved application valid for 12 months from date of approval.Submit PDF to aogcc.permitting@alaska.gov By Grace Christianson at 7:49 am, Dec 10, 2024 Digitally signed by Dan Marlowe (1267) DN: cn=Dan Marlowe (1267) Date: 2024.12.09 13:48:39 - 09'00' Dan Marlowe (1267) 324-690 X NFT required within 10 days of returning well to production. BOP test to 2500 psi BJM 12/13/24 DSR-12/16/24SFD 12/11/2024 10-404 *&: Jessie L. Chmielowski Digitally signed by Jessie L. Chmielowski Date: 2024.12.17 10:22:00 -09'00'12/17/24 RBDMS JSB 121824 ESP Swap RWO Well: Dolly Varden D-20 Well Name:D-20 API Number:50-733-20203-00-00 Current Status:Failed ESP Oil Producer Leg:B-1 (SE) Regulatory Contact:Juanita Lovett (8332)Permit to Drill Number:169-095 First Call Engineer:Ryan Rupert (907) 301-1736 (c) Second Call Engineer:Dan Marlowe (907) 398-9904 (c) Maximum Expected BHP:2,464 psi @ 8,747’ TVD 36 day shut in 7/11/24 Max. Potential Surface Pressure: 1590 psi Using 0.1 psi/ft This is a no-flow well 04/15/2017 Last Casing Test: 02/28/2015 at 9,461’ to 2,500 psig for 30 minutes on chart Brief Well Summary Dolly Varden D-20 is a G-zone / Hemlock oil producer. The D-20 well is currently completed with a failed ESP that was installed July 2017. The well is currently producing on gas lift. This workover will replace the combo Gas-Lift / ESP completion to restore productivity. The goal of this project is to pull the failed ESP and replace with a new ESP completion Pertinent wellbore information: - Max inclination: ~21-degree sail angle from 1700 – 10,500’ MD - Last casing test: 02/28/2015 at 9,461’ to 2,500 psig for 30 minutes on chart - Pertinent History o 10/20/24: ESP died after a 7.26yr run (gross fluid ~1500BPD) Well set-up for GL (gross fluid rate ~ 800BPD) o 7/18/17 Failed ESP replaced after 92day run (erosion cut gas separator) o 4/5/17: Most recent No-Flow Test Passed o 3/31/17 Replace ESP that had holes in it but still ran 2.04yr run o 11/3/15 Pump Xylene followed by 3000gal 10% HCL o Feb/Mar 2015 RWO Remove cement plug in well Install 7-5/8” casing from surface to 9,467’, cemented MIT of 7-5/8" casing from 9461' and above to 2500psi PASS Mill existing packer from 9601’ MD with 5-1/2” tapered mill and 4.88” string mill Pushed packer downhole from 9,601’ MD to 10,045’ MD Can't get past 10,045' MD (Fish on top of Baker packer at 10,068’) Re-perforate G and Hemlock zones ESP installed ESP Swap RWO Well: Dolly Varden D-20 RWO Procedure: 1. MIRU HAK 404 2. Circulate well: a. Work over fluid will be filtered inlet water (8.4ppg) b. Ensure any wellbore fluids are fully displaced with KWF either via circulation or bullheading c. Tubing volume = 79bbls d. IA to ESP = 308bbls e. Liner below ESP = 46bbl 3. Set BPV/TWC, ND tree, NU Hilcorp BOP stack (see attached) a. Notify AOGCC 48 hours in advance for witness b. Test to 250psi Low /2,500psi High / 2,500psi Annular c. BOPE will be used as needed to circulate the well 4. Pull BPV/TWC 5. BOLDS and unseat hanger 6. POOH laying down 3-1/2” ESP/GL completion 7. PU work string 8. MU 7-5/8” x 7” casing cleanout assembly 9. RIH and mill/cleanout casing to shallowest packer at target depth = ±10,068’ MD 10. POOH and lay down cleanout BHA and work string 11. MU 7-5/8” test packer 12. Set packer at ±9,300’ MD / 8,889’ TVD (Top Perf 9,370’) 13. MIT of 7-5/8” casing to 2250psi (0.25 x 8,889’ TVD = 2223psi) 14. POOH with test packer 15. Pickup ESP/GL completion a. Bottom ESP to be set at ±9,150’ MD b. No packer nor SSSV are planned 16. Set BPV/TWC, ND BOP 17. NU tree and test, pull BPV/TWC 18. RDMO RWO crew and equipment With performing a cleanout, another No Flow Test will be required. Conduct NFT post-rig after ~10 days of stable production Attachments: 1. Current Wellbore Schematic 2. Proposed Wellbore Schematic 3. Current/Proposed Wellhead Diagram (no changes) 4. BOP Drawing 5. 404 Fluid flow diagram 6. RWO Sundry Change Form With performing a cleanout, another No Flow Test will be required. Conduct NFT post-rig after ~10 days of stable production Updated by: JLL 11/21/24 SCHEMATIC Trading Bay Unit Well: D-20 PTD: 169-095 API: 50-733-20203-00 Completed: 07/18/2017 PBTD = 10,430’ TD = 10,506’ MAX HOLE ANGLE = 21q, @ 2100’ RKB to TBG Head = 41.8’ 11 HK-1 HK-4 HK-5 HK-6 12 HK-3 Fill tagged on 8/26/88 @ 10,201’ No Joy on 2-1/16” tbg thru pkr. during WO in 11/83 Csg Shoe @ 9660’ DIL Fill tagged on 03/18/15 @ 10,045’ G-2 G-4 G-5 DV Collar 5,204’ 10 1-9 A CBL Good BondFrom 8450’ to 9450’CBL Good BondFrom 9960’ to 10,400’CBL Good Bond9663’ to 9669’9677’ to 9680’9744’ to 9749’Brief Details & Info: To date Spudded D-20 on 9/20/69. TD @ 10,506’ on 10/25/69. Completed & RR on 11/06/69. xHole Section MWT:xApproximate Rotating hrs: o 17-1/2” to 3050’ 9.9 to 10 ppg o 33” 60 hrs o 12-1/4” to 9,748’ 9.8 to 10 ppg o 13-3/8” 285 hrs o 8-1/2” to 10,506 o 9-5/8” 51 hrs o 7” 16 hrs A 4/29/75 D-27 collided w/ D-20 while drilling 17-1/2” surface hole.Communication to Inlet. Spotted 500sx of G cmt @ 400’ in D-27. Possible length of breach in 13-3/8” is 1488’ to 1497’. Penetration in D-20 9-5/8” @ 1497’. 7/75 WO sqz’d 9-5/8” csg @ 1497’ 4x. Total cmt placed 650 sx. JEWELRY DETAIL NO Depth (MD) Depth (TVD) ID OD Item 32.70’ 32.70’ 2.992” 11.000 ” Tubing hanger: FMC-TC-ESP, 11”x3-1/2” IBT lift & susp, 300-4 seal pocket, w/ 3" Type 'H' BPV profile, 2- 3/8" CCL, alloy material 10 9,055’ 8,657’ - 5.130” Bolt on Discharge 9,056’ 8,658’ - 5.380” Pump - Summit SJ2800 DH15 - (x2), 1-114 Stg & 1-76 Stg 9,095’ 8,695’ - 5.130” Intake 9,096’ 8,696’ - 5.130” Seals (x2) – Summit BPBSL 9,114’ 8,713’ - 5.620” Motor - 500HP Summit KMS2 (500HP/3305V/83A) 9,150’ 8,747’ - 5.620” Gauge (Zenith) / Centralizer / Anode 11 10,068’ 9,615’ 3.250 Baker Model “D” Pkr. 10,078’ 9,624’ 2.750 Otis “X” Nipple, size 2.75 10,086’ 9,632’ 3.000 Bell Guide 12 10,198’ 9,737’ 3.250 Baker Model “D” Pkr. 10,206’ 9,745’ 2.625 Otis “Q” Nipple, size 2.625 10,212’ 9,750’ 3.000 Mule Shoe CASING DETAIL SIZE TYPE WT GRADE CONN ID TOP BTM. 33” Conductor Surf 400’ 13-3/8” Surf Csg 61 K-55 Seal Lock 12.515 Surf 3,006’ 9-5/8” Prod Csg 40 N-80 Butt 8.835 Surf 4,390’ 43.5 N-80 Butt 8.755 4,390’ 6,156’ 47 S-95 Butt 8.681 6,156’ 7,080’ AR-95 Seal Lock 7,080’ 9,674’ 7-5/8” Tie-Back 29.7 L-80 SLIJ-II 6.875 Surf 9,467’ 7" Liner 29 N-80 X-Line 6.185 9,463’ 10,480’ TUBING DETAIL 3-1/2” 9.2# L-80 Supermax 2.992 Surf 9,055’ PERFORATION DETAIL Zone Top (MD) Btm(MD) Top (TVD)Btm (TVD) Amt. SPF Last Perf Date Present Condition G-2 9,370' 9,388' 8,955' 8,972' 18' 5 03/19/2015 Open G-2 9,421’ 9,445’ 9,004’ 9,026’ 24’ 6 03/29/2017 G-4 9,478' 9,484' 9,057' 9,063' 6' 5 03/19/2015 Open G-5 9,610’ 9,627’ 9,182’ 9,198’ 17 5 03/19/2015 Open Sqz 9,680' 9,681' 9,248' 9,249' 1' 4 11/02/1969 Sqz 100 sx cmt. Sqz 9,750' 9,751' 9,315' 9,315' 1' 4 10/30/1969 Sqz 75 sx cmt. HK-1 9,820' 9,885' 9,381' 9,442' 65' 20 06/15/1992 Open f/ Production HK-1 9,828' 9,862' 9,388' 9,420' 34' 5 03/19/2015 Open HK-3 9,905' 9,950' 9,461' 9,503' 45' 16 06/15/1992 Open f/ Production HK-4 9,908' 9,932' 9,464' 9,486' 24' 5 03/19/2015 Open HK-4 9,950' 10,065' 9,503' 9,611' 115' 16 06/15/1992 Open f/ Production HK-4 9,964' 9,986' 9,516' 9,537' 22' 5 03/19/2015 Open HK-5 10,070' 10,190' 9,616' 9,730' 120' 16 Jul-75 Open f/ Production HK-6 10,230' 10,260' 9,767' 9,796' 30' 4 Jul-75 Open f/ Production GAS LIFT MANDRELS STA MD TVD ID Type Port Valve Psc Date 1 2,305’ 2,249’ 2.867” SFO-1 16 Dome 1091 10/28/24 2 4,149’ 3,985’ 2.867” SFO-1 16 Dome 1071 10/28/24 3 5,526’ 5,300’ 2.867” SFO-1 20 Dome 1051 10/28/24 4 6,275’ 6,011’ 2.867” SFO-1 Dummy 07/17/2017 5 6,754’ 6,471’ 2.867” SFO-1 20 Dome 1031 10/28/24 6 7,301’ 6,986’ 2.867” SFO-1 24 Dummy 11/13/24 7 7,848’ 7,502’ 2.867” SFO-1 Dome 1011 11/13/24 8 8,362’ 7,994’ 2.867” SFO-1 Orifice 11/14/24 9 9,009’ 8,614’ 2.867” SFO-1 Open 10/25/24 Updated by: JLL 12/06/24 PROPOSED Trading Bay Unit Well: D-20 PTD: 169-095 API: 50-733-20203-00 Completed: FUTURE PBTD = 10,430’ TD = 10,506’ MAX HOLE ANGLE = 21q, @ 2100’ RKB to TBG Head = 41.8’ 11 HK-1 HK-4 HK-5 HK-6 12 HK-3 Fill tagged on 8/26/88 @ 10,201’ No Joy on 2-1/16” tbg thru pkr. during WO in 11/83 Csg Shoe @ 9660’ DIL Fill Cleanout to ±10,068’ MD G-2 G-4 G-5 DV Collar 5,204’ 10 1-9 A CBL Good BondFrom 8450’ to 9450’CBL Good BondFrom 9960’ to 10,400’9663 to9669’9677’ to9680’9744’toBrief Details & Info: To date Spudded D-20 on 9/20/69. TD @ 10,506’ on 10/25/69. Completed & RR on 11/06/69. xHole Section MWT:xApproximate Rotating hrs: o 17-1/2” to 3050’ 9.9 to 10 ppg o 33” 60 hrs o 12-1/4” to 9,748’ 9.8 to 10 ppg o 13-3/8” 285 hrs o 8-1/2” to 10,506 o 9-5/8” 51 hrs o 7” 16 hrs A 4/29/75 D-27 collided w/ D-20 while drilling 17-1/2” surface hole.Communication to Inlet. Spotted 500sx of G cmt @ 400’ in D-27. Possible length of breach in 13-3/8” is 1488’ to 1497’. Penetration in D-20 9-5/8” @ 1497’. 7/75 WO sqz’d 9-5/8” csg @ 1497’ 4x. Total cmt placed 650 sx. JEWELRY DETAIL NO Depth (MD) Depth (TVD) ID OD Item 32.70’ 32.70’ 2.992” 11.000 ” Tubing hanger: FMC-TC-ESP, 11”x3-1/2” IBT lift & susp, 300-4 seal pocket, w/ 3" Type 'H' BPV profile, 2- 3/8" CCL, alloy material 10 ±9,055’±8,657’- 5.130” Bolt on Discharge - 5.380” Pump -5.130” Intake - 5.130” Seals - 5.620” Motor ±9,150’±8,747’- 5.620” Centralizer / Anode 11 10,068’ 9,615’ 3.250 Baker Model “D” Pkr. 10,078’ 9,624’ 2.750 Otis “X” Nipple, size 2.75 10,086’ 9,632’ 3.000 Bell Guide 12 10,198’ 9,737’ 3.250 Baker Model “D” Pkr. 10,206’ 9,745’ 2.625 Otis “Q” Nipple, size 2.625 10,212’ 9,750’ 3.000 Mule Shoe CASING DETAIL SIZE TYPE WT GRADE CONN ID TOP BTM. 33” Conductor Surf 400’ 13-3/8” Surf Csg 61 K-55 Seal Lock 12.515 Surf 3,006’ 9-5/8” Prod Csg 40 N-80 Butt 8.835 Surf 4,390’ 43.5 N-80 Butt 8.755 4,390’ 6,156’ 47 S-95 Butt 8.681 6,156’ 7,080’ AR-95 Seal Lock 7,080’ 9,674’ 7-5/8” Tie-Back 29.7 L-80 SLIJ-II 6.875 Surf 9,467’ 7" Liner 29 N-80 X-Line 6.185 9,463’ 10,480’ TUBING DETAIL 3-1/2” Surf ±9,055’ PERFORATION DETAIL Zone Top (MD) Btm(MD) Top (TVD)Btm (TVD) Amt. SPF Last Perf Date Present Condition G-2 9,370' 9,388' 8,955' 8,972' 18' 5 03/19/2015 Open G-2 9,421’ 9,445’ 9,004’ 9,026’ 24’ 6 03/29/2017 G-4 9,478' 9,484' 9,057' 9,063' 6' 5 03/19/2015 Open G-5 9,610’ 9,627’ 9,182’ 9,198’ 17 5 03/19/2015 Open Sqz 9,680' 9,681' 9,248' 9,249' 1' 4 11/02/1969 Sqz 100 sx cmt. Sqz 9,750' 9,751' 9,315' 9,315' 1' 4 10/30/1969 Sqz 75 sx cmt. HK-1 9,820' 9,885' 9,381' 9,442' 65' 20 06/15/1992 Open f/ Production HK-1 9,828' 9,862' 9,388' 9,420' 34' 5 03/19/2015 Open HK-3 9,905' 9,950' 9,461' 9,503' 45' 16 06/15/1992 Open f/ Production HK-4 9,908' 9,932' 9,464' 9,486' 24' 5 03/19/2015 Open HK-4 9,950' 10,065' 9,503' 9,611' 115' 16 06/15/1992 Open f/ Production HK-4 9,964' 9,986' 9,516' 9,537' 22' 5 03/19/2015 Open HK-5 10,070' 10,190' 9,616' 9,730' 120' 16 Jul-75 Open f/ Production HK-6 10,230' 10,260' 9,767' 9,796' 30' 4 Jul-75 Open f/ Production GAS LIFT MANDRELS STA MD TVD ID Type Port Valve Psc Date 1 ±2,305’±2,249’2.867” GLM #1 2 ±4,149’±3,985’2.867”GLM #2 3 ±5,526’±5,300’2.867”GLM #3 4 ±6,275’±6,011’2.867”GLM #4 5 ±6,754’±6,471’2.867”GLM #5 6 ±7,301’±6,986’2.867”GLM #6 7 ±7,848’±7,502’2.867”GLM #7 8 ±8,362’±7,994’2.867”GLM #8 9 ±9,009’±8,614’2.867”GLM #9 Dolly Varden Platform D-20 Current 12/19/2014 Dolly Varden D-20 13 3/8 X 9 5/8 X 7 5/8 X 2 7/8 Tubing hanger, FMC-TC-ESP, 11 X 3 ½ NS-CT lift and susp, 300-4 seal pocket, w/ 3'’ Type H BPV profile, 2- 3/8 CCL, Alloy material Casing head, CIW-WF, 13 5/8 3M X 13 3/8 casing thread bottom, w/ 2- 2 1/16 5M EFO Valve, lower master, WKM-M, 3 1/8 5M FE, HWO, T-24 Valve, wing, WKM-M, 2 1/16 5M FE, HWO, T-24 Valve, swab, WKM-M, 3 1/8 5M FE, HWO, T-24 BHTA, Bowen, 3 1/8 5M FE X 3'’ Bowen Quick Union Valve, WKM-M, 3 1/8 5M FE, w/ 15'’ OMNI operator Multibowl wellhead assy, Cactus MBS-2 13 5/8 3M x 11 5M,w/ 4- 2 1/16 5M SSO, prepped for 7 5/8 mandrel hanger, and tubing hanger, 9 5/8 HPS bottom Valve, WKM-M, 2 1/16 5M FE, HWO, DD Valve, WKM-M, 2 1/16 5M FE, HWO, DD Valve, CIW-F, 2 1/16 3M FE, HWO, AA trim Adapter, FMC-A-5-EC, 11 5M rotating flange x 3 1/8 5M rotating top, 300-4 pocket prep, 2- CCL ports, 3.266 centers Dolly Varden Platform BOP Stack Shaffer SL 13 5/8 5M 2 7/8-5.5 variables Blinds 2.00' Riser 13 5/8 5M FE X 13 5/8 5M FE Spacer spool 13 5/8 5M FE X 11 5M 4.54' 2.83' Choke and Kill valves 2 1/16 5M Mud Cross 3 1/8 5M EFO 4.30'Hydril GK 13 5/8-5000 DSA 3 X 2DSA 3 X 220.40' 1.33' HILCORP ALASKA, LLC Hilcorp Alaska, LLCHilcorp Alaska, LLCChanges to Approved Sundry ProcedureSubject: Changes to Approved Sundry Procedure for Well: Trading Bay Unit D-20 (PTD 169-095)Sundry #: XXX-XXXAny modifications to an approved sundry will be documented and approved below. Changes to an approved sundry will be communicated to theAOGCC by the rig workover (RWO) “first call” engineer. AOGCC written approval of the change is required before implementing the change.Sec Page Date Procedure Change New 403Required?Y / NHAKPreparedBy(Initials)HAKApprovedBy(Initials)AOGCC WrittenApproval Received(Person and Date)Approval:Asset Team Operations Manager DatePrepared:First Call Operations Engineer Date STATE OF ALASKA • ARKA OIL AND GAS CONSERVATION COMMISSION RECEIVED REPORT OF SUNDRY WELL OPERATIONS JUL 2 8 2017 1.Operations Abandon 0 Plug Perforations 0 Fracture Stimulate ❑ Pull Tubing El own 0 Performed: Suspend ❑ Perforate 0 Other Stimulate ❑ Alter Casing❑ Ch n p Tgram 0 Plug for Redrill ❑ Perforate New Pool 0 Repair Well ❑ Re-enter Susp Well 0 Other:GUESP Completion 0 2.Operator 4.Well Class Before Work: 5.Permit to Drill Number: Name: Hilcorp Alaska,LLC Development D Exploratory❑ 169-095 3.Address: 3800 Centerpoint Drive,Suite 1400 Stratigraphic ❑ Service ❑ 6.API Number: Anchorage,AK 99503 50-733-20203-00-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL0018729 Trading Bay Unit D-20 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pool(s): N/A McArthur River Field/Middle Kenai G and Hemlock Oil Pools 11.Present Well Condition Summary: Total Depth measured 10,506 feet Plugs measured N/A feet true vertical 10,028 feet Junk measured 10,068&10,198 feet Effective Depth measured 10,045 feet Packer measured 10,068&10,198 feet true vertical 9,593 feet true vertical 9,615&9,737 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 400' 33" 400' 399' Surface 3,006' 13-3/8" 3,006' 2,905' 3,090 psi 1,540 psi Intermediate 9,674' 9-5/8" 9,674' 9,242' 5,750 psi 3,090 psi Production 9,467' 7-5/8" 9,467' 9,047' 6,890 psi 4,790 psi Liner 1,017' 7" 10,480' 1,003' 8,160 psi 7,020 psi Perforation depth Measured depth 9,370-10,260 feet SC A!4i�Ns1ED P f 14 I 2(,1,% True Vertical depth 8,955-9,796 feet Tubing(size,grade,measured and true vertical depth) 3-1/2" 9.2#/L-80 9,055(MD) 8,657(TVD) Baker Mod D Pkr 10,068 MD/9,615 TVD Packers and SSSV(type,measured and true vertical depth) Baker Mod D Pkr 10,198 MD/9,737 TVD SSSV:N/A 12.Stimulation or cement squeeze summary: 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: 239 37 2003 106 120 Subsequent to operation: 267 27 2608 124 124 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations E Exploratory ❑ DevelopmentO Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run 0 16.Well Status after work: Oil 0 Gas ❑ WDSPL❑ Printed and Electronic Fracture Stimulation Data 0 GSTOR ❑ WINJ ❑ WAG ❑ GINJ❑ 3USP❑ SPLUG❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: 317-307 Authorized Name: Stan W.Golis Contact Name: Dan Marlowe Authorized Title: Operations Manager Contact Email: dmarloweCS)hilcorp.com Authorized Signature: Date: 1 i le,/t, Contact Phone: (907)283-1329 tf-i Form 10-404 Revised 4/2017 #(107 RBDMS t/t) AN C - 1 2017 Submit Original.Only II • • Trading Bay Unit Well: D-20 SCHEMATIC PTD: 169-095 API: S0-733-20203-00 llileorp Alaska,LLC Completed: 07/18/2017 RKB to TBG Head=41.8' CASING DETAIL SIZE TYPE WT GRADE CONN ID TOP BTM. ', 33" Conductor Surf 400' y 13-3/8" Surf Csg 61 K-55 Seal Lock 12.515 Surf 3,006' 40 N-80 Butt 8.835 Surf 4,390' A .fit•. % i',ti:,, 9-5/8" Prod Csg 43.5 N-80 Butt 8.755 4,390' 6,156' 4'1' '' ti{r, S-95 Butt 6,156' 7,080 }f 47 AR-95 Seal Lock 8.681 7,080' 9,674' ,: ; 4tif• 7-5/8" Tie-Back 29.7 L-80 SLID-II 6.875 Surf 9,467' •I• ` ,;1{ 7" Liner 29 N-80 X-Line 6.185 9,463' 10,480' r { t ti}; TUBING DETAIL ti tir, 3-1/2" 9.2# L-80 Supermax 2.992 Surf 9,055' 1• - Lf' ''" JEWELRY DETAIL 4 tif ':. `.,tif, 1-9III d NO Depth Depth ID OD Item DV Collar (MD) (ND) 5,204' Tubing hanger: FMC-TC-ESP,11"x3-1/2"IBT lift&susp,300-4 32.70' 32.70' 2.992" 11.000" seal pocket,w/3"Type'H'BPV profile,2-3/8"CCL,alloy material 1 2,305' 2,249' 2.867" 5.313" GLM#1-SF0-1 f2 4,149' 3,985' 2.867" 5.313" GLM#2-SF0-1 3 5,526' 5,300' 2.867" 5.313" GLM#3-SF0-1 t / 10 4 6,275' 6,011' 2.867" 5.313" GLM#4-SFO-1 4 5 6,754' 6,471' 2.867" 5.313" GLM#5-SF0-1 c32 ,'�% G 2 ,, 6 7,301' 6,986' 2.867" 5.313" GLM#6-SFO-1 ° I , '- 7 7,848' 7,502' 2.867" 5.313" GLM#7-SF0-1 G-4 8 8,362' 7,994' 2.867" 5.313" GLM#8-SFO-1 9 9,009' 8,614' 2.867" 5.313" GLM#9-SFO-1 9,055' 8,657' - 5.130" Bolt on Discharge G-5 9,056' 8,658' - 5.380" Pump-Summit 512800 DH15-(x2),1-114 Stg &1-76 Stg ' ' 10 9,095' 8,695' - 5.130" Intake =v csg shoe 9,096' 8,696' - 5.130" Seals(x2)-Summit BPBSL @ 9660'DIL 'sib, f> =t; 9,114' 8,713' - 5.620" Motor-500HP Summit KMS2(500HP/3305V/83A) 82..9.: - 9,150' 8,747' - 5.620" Gauge(Zenith)/Centralizer/Anode 'LIP.; {" " 10,068' 9,615' 3.250 Baker Model"D"Pkr. 11 10,078' 9,624' 2.750 Otis"X"Nipple,size 2.75 HK-1 10,086' 9,632' 3.000 Bell Guide 10,198' 9,737' 3.250 Baker Model"D"Pkr. 12 10,206' 9,745' 2.625 Otis"Q"Nipple,size 2.625 10,212' 9,750' 3.000 Mule Shoe -1K-3 _ PERFORATION DETAIL r ,Fill tagged Top to,on 03n8n6610,045 K-4 Zone Top(MD) Btm(MD) (TVD) Btm(ND) Amt. SPF Last Perf Date Present Condition d.•.•.•�"I3.•.• G-2 9,370' 9,388' 8,955' 8,972' 18' 5 03/19/2015 Open G-2 9,421' 9,445' 9,004' 9,026' 24' 6 03/29/2017 2 ��I '. 04 9,478' 9,484' 9,057' 9,063' 6' 5 03/19/2015 Open r•# -„ 11 G-5 9,610' 9,627' 9,182' 9,198' 17 5 03/19/2015 Open ' Sqz 9,680' 9,681' 9,248' 9,249' 1' 4 11/02/1969 Sqz 100 sx cmt. l'.7;' x/,, II Sqz 9,750' 9,751' 9,315' 9,315' 1' 4 10/30/1969 Sqz 75 sx cmt. HK-1 9,820' 9,885' 9,381' 9,442' 65' 20 06/15/1992 Open f/Production HK-1 9,828' 9,862' 9,388' 9,420' 34' 5 03/19/2015 Open HK-3 9,905' 9,950' 9,461' 9,503' 45' 16 06/15/1992 Open f/Production . 14,1 8/sageg@1ozo1 ' HK-5 HK-4 9,908' 9,932' 9,464' 9,486' 24' 5 03 19/2015 Open 4, HK-4 9,950' 10,065' 9,503' 9,611' 115' 16 06/15/1992 Open f/Production HK-4 9,964' 9,986' 9,516' 9,537' 22' 5 03/19/2015 Open No,y n 2-1/18"tbg thryPk.d",ing _ 12 HK-5 10,070' 10,190' 9,616' 9,730' 120' 16 Jul-75 Open f/Production NO In 11B' _ HK-6 10,230' 10,260' 9,767' 9,796' 30' 4 Jul-75 Open f/Production Vii` t • Brief Details&Info:To date - -. Spudded D-20 on 9/20/69.TD @ 10,506'on 10/25/69.Completed&RR on 11/06/69. •Hole Section MWT: •Approximate Rotating hrs: o 17-1/2"to 3050' 9.9 to 10 ppg o 33" 60 hrs K-6 0 12-1/4"to 9,748' 9.8 to 10 ppg o 13-3/8" 285 hrs , , ,•;•;•, ,•;• 0 8-1/2"to 10,506 0 9-5/8" 51 hrs 1«.• 0 7" 16 hrs A 4/29/75 D-27 collided w/D-20 while drilling 17-1/2"surface hole.Communication to Inlet.Spotted 500sx of G cmt @ 400' in D-27.Possible length of breach in 13-3/8"is 1488'to 1497'.Penetration in D-20 9-5/8"@ 1497'. PBTD=10,430' TD=10,506' MAX HOLE ANGLE=21°,@ 2100' 7/75 WO sqz'd 9-5/8"csg @ 1497'4x.Total cmt placed 650 sx. Updated: 07/27/17 by AL • • Hilcorp Alaska, LLC Well Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date D-20 Moncla 404 50-733-20203-00 169-095 7/13/17 7/18/17 Daily Operations: 07/13/17-Thursday Rig and crane crews, 1- 5 Star, expeditor and WSM being shuttled to Dolly platform from heliport. Settled all W/O personnel onboard and held PJSM w/ production. Notified AOGCC of proposed BOPE test on 7/15/17. Laid derrick in headache rack while rigging up to flush well with FIW. Generated NPFT and began flushing well with FIW at 3 bpm 310 psi sending returns to production header. Moved koomey unit and choke house- repositioned crane stairway support and moved jacking cylinders into place. 1300 hrs caught returns momentarily at 480 bbls pumped then lost returns. Pumped 600 bbls-total w/o sustained returns-shutdown pump. Completed move over D-20. Lined up to pump down casing taking returns up tb while rigging down jacking equipment. Set koomey house and choke house in place. Pumped FIW in rev at 3 bpm 270 psi while continuing to setup W/O package. Secured rig carrier-spotting racking mat and landing w/steps across double and racking mat beams- repositioned stairs to carrier walkways. Began getting partial returns at 2000 hrs. Continued positioning equipment for well work. Shutdown pump and monitored well-on vacuum on both sides. Installed BPV and N/D tree- M/U 3 1/2" NS-CT LH test sub in tb hanger. N/U 13 5/8" 5M BOPE w/ 11" 5M adapter on btm. Connected choke and kill lines to mud cross and koomey lines to hyd components. Shutdown from 3-4 AM due to lightning. Presently torqueing down stack. 07/14/17- Friday Finished torqueing BOP stack. Raised and scoped out derrick securing all guy lines. Mounted rig floor installing supports, wind walls and stairways- loaded floor w/ handling tools and tongs. M/U 3 1/2" 8rd test jt w/ pumpin, SV& IBOP on top, buttress XO on btm and screwed into blanked & ported test sub. Began pretesting BOPE to 250 psi low 3000 psi high- worked thru minor leaks. Test#3 -slight bleed off on high test (3000 psi), leak at Cl valve flanged connection,tighten flange & re-test for pass.Test 6- bleed off during low test (250 psi),grease Cl valve, re-test for pass. Changed swabs on rig pump. Clean and organize prepping for AOGCC witnessed BOPE test. Arranged and ordered all koomey, choke, pneumatic and hydraulic lines beneath carrier. Assemble NOS T-bar and hung same with cat line. Clean drill deck, wipe down hand rails. Organize parts connex. • S Hilcorp Alaska, LLC Well Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date D-20 Moncla 404 50-733-20203-00 169-095 7/13/17 7/18/17 07/15/17-Saturday Continued cleaning and organizing in preparation for AOGCC arrival for witnessed BOPE test.Tested all BOPE to 250 psi low 3000 psi high as per Sundry in accordance to Hilcorp and AOGCC requirements (lost 2 hrs recovering backed off x-over sub in top of hanger- pulled BPV and set 2-way check prior to testing blinds). Performed successful accumulator draw-down test. Test witnessed by Adam Earl/AOGCC. Backed out hold down pins in tb head while R/U Summit sheaves in derrick. Screwed into hanger w/ landing jt, opened annulus then pulled 130k to unseat hanger- pulled uphole at 100k. Lined up to pumped in rev sending returns to prod header. Pumped 200 bbls at 3 bpm 0 psi (no returns). Pull tubing hanger to surface, L/D 3-1/2" landing joint and tubing hanger. POOH L/D Jts. 1-4 of 3-1/2" 9.2# L-80 SuperMax production tubing.Tie back power cable and flatpack to Summit spoolers. POOH with ESP/SPM completion standing back 3-1/2" 9.2# L-80 SuperMax production tubing, laying down GLMs. Pump 10 BBL FIW every 20 stands. 18 stands in derrick (1366'), test insulation at splice- PASS. 58 stands in derrick (40461 test insulation at splice - PASS. Damaged armor shield found across 2nd GLM OOH (4146' -4167'), damage under clamp at GLM appears to occurred during up movement of completion, remaining damaged length flattened from "rubbing". Continue POOH with ESP/SPM completion standing back 3-1/2" 9.2# L-80 SuperMax production tubing, laying down GLMs. 84 stands in the derrick(5814'),test insulation at splice - PASS. Summit swaped out power cable spool for empty spool. Continue POOH with ESP/SPM completion standing back 3-1/2" 9.2# L-80 SuperMax production tubing, laying down GLMs. 104 of 132 stands OOH at report time = 1,931'. 07/16/17-Sunday Continued pulling ESP/SPM production string from 1,931', standing back tubing and laying down SPMs. 0900 hrs observed no sign of damage at last SPM (8,987')- cable still shows shorted reading below mandrel area. Found some scale at the top of discharge and ported sub. Found hole at btm of gas separator section w/severe damage to power cable and minor damage to flat pack(pics in '0' drive). Pumps checked out good- both turned smooth w/no radial play. Found metal flaking and signs of wear in top of motor which determined that it would not be reused. OOH w/assy. Pumped 100 bbls FIW while clearing and cleaning floor. Prepped rig floor to P/U ESP/SPM assy. P/U 5 5/8" 500 HP (fresh) motor section w/ gauge-serviced same- M/U anode and lowered it in hole. Connected flat pack lines- M/U lower& upper tandem seal sections. Spliced in power cable and checked insulation. M/U standard intake, double pump sections, ported pressure sub, bolt on discharge and handling jt w/x-over sub (pulled Pollard S/L set packoff at surface prior to M/U). M/U GLM# 1. RIH w/3-1/2" 9.2# L-80 SuperMax tubing (re-used) out of derrick. Lower GLM# 1 on 3-1/2" tubing to clear BOPE stack. Pump 30 BBL FIW. Drifting and torqueing tb to specs.TIH with ESP/SPM completion on 3-1/2" 9.2# L-80 SuperMax tubing (re- used). Rabbit each stand out of derrick,test insulation every 1000'. Pump 20 BBL FIW every hour on the hour. Continue TIH with ESP/SPM completion on 3-1/2" 9.2# L-80 SuperMax tubing (re-used). Rabbit each stand out of derrick. RIH w/GLM#3. Stop to test insulation - PASS. Pump 127 BBL FIW to load the hole (needed to immerse tool in fluid for electrical checks). Continue TIH with ESP/SPM completion on 3-1/2" 9.2# L-80 SuperMax tubing (re-used). Rabbit each stand out of derrick, test insulation every 1000'. Pump 20 BBL FIW every hour on the hour. 56 stands in hole at report time = 3,964'. • ! Hilcorp Alaska, LLC Well Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date D-20 Moncla 404 50-733-20203-00 169-095 7/13/17 7/18/17 Daily Operations: E. 07/17/17- Monday Continue RIH from 3,964' w/ ESP/SPM assy on 3 1/2" 9.2# L-80 (rerun) tb-drifting and torqueing to specs- pumping 20 bbls FIW every hr or as needed to make elec checks-checking power cable every 1000'. 0700 hrs repaired shielding on power cable at—4,560'. Made splice in power cable at 6,752' (on 98th stand). Finished RIH with ESP/SPM assy. NOS rep M/U tubing hanger. Summit builds penetrator splice and plumbed penetrator through tubing hanger. NOS rep plumbed control lines through tubing hanger. Slacked off, SOW= 66K, and land hanger with 66K down on hanger head. Estimated PUW= 110K with end of pump at 9149.99'. Run in hold-down pins energize tubing hanger seal. L/D landing joint and set BPV. Cleared rig floor of all Summit equipment,tongs and handling equipment. Removed wind walls and rig floor. Scoped down derrick and laid over in headache rack. N/D BOPE stack. Began N/U tree. 07/18/17-Tuesday Finished N/U tree-void tested to 500 psi f/5 mins 5000 psi f/ 15 mins. Broke down/packed up rig pump, tank, choke house and koomey unit. Unspooled all drill and cat lines from derrick- prepped to move W/O package to King Salmon. Assisted production w/tree hookups- pulled BPV and set 2-way check-shell tested tree to 5000 psi f/ 15 mins. Released pressure and turned well over to production. ti OF ,,,t • • 4tAs• yy��6. THE STATE Alaska Oil and Gas OAT /H� 1IIr� � � Conservation Commission �1 1L1 1SJ1��1 1 s} - 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 N-jr ° Main: 907.279.1433 Off,A,, .S Fax: 907.276.7542 www.aogcc.alaska.gov Stan W. Golis Operations Manger S( ,® JUL (1 Hilcorp Alaska, LLC 17, 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: McArthur River Field, Middle Kenai G and Hemlock Oil Pool, TBU D-20 Permit to Drill Number: 169-095 Sundry Number: 317-307 Dear Mr. Golis: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown,a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, • Hollis S. French Chair DATED this 3 day of July, 2017. RBD!VIS L'— JUL 1 1 2017 • 0 fikCEIVED STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION ,it!( 0 5 2017 APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 AG CC, 1.Type of Request: Abandon ❑ Plug Perforations 0 Fracture Stimulate ❑ Repair Well ❑ Operations shutdown❑ Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing Q ' Change Approved Program❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other:Combo GUESP Completion❑' 2.Operator Name: 4.Current Well Class: 5. Permit to Drill Number: Hilcorp Alaska, LLC Exploratory 0 Development ❑✓ ' 169-095 ' 3.Address: 3800 Centerpoint Dr,Suite 1400 Stratigraphic ❑ Service 0 6.API Number: Anchorage Alaska 99503 50-733-20203-00 - 7.If perforating: 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? CO 228A Trading Bay Unit/D-20 Will planned perforations require a spacing exception? Yes ❑ No ❑� / 9.Property Designation(Lease Number): 10. Field/Pool(s): ADL0018729, McArthur River Field/Middle Kenai G and Hemlock Oil Pools ' 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP(psi): Plugs(MD): Junk(MD): 10,506 10,028, 10,045 , 9,593 s 2,542 psi N/A 10,068&10,198 Casing Length Size MD TVD Burst Collapse Structural Conductor 400' 33" 400' 399' Surface 3,006' 13-3/8" 3,006' 2,905' 3,090 psi 1,540 psi . Intermediate 9,674' 9-5/8" 9,674' 9,242' 5,750 psi 3,090 psi Production 9,467' 7-5/8" 9,467' 9,047' 6,890 psi 4,790 psi Liner 1,017' 7" 10,480' 10,003' 8,160 psi 7,020 psi Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 9,370-10,260 • 8,955-9,796 3-1/2" 9.2#/L-80 9,036' Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): Model"D"Pkr(x2)&SSSV 10,068'(MD)9,615(ND);10,198(MD)9,737(TVD)&N/A;N/A 12.Attachments: Proposal Summary Q Wellbore schematic ❑✓ 13.Well Class after proposed work: Detailed Operations Program 0 BOP Sketch ❑✓ Exploratory ❑ Stratigraphic ❑ Development 0 r Service 0 14. Estimated Date for 15.Well Status after proposed work: July 15,2017 Commencing Operations: OIL 2 • WIND 0 WDSPL 0 Suspended ❑ 16.Verbal Approval: Date: GAS 0 WAG 0 GSTOR ❑ SPLUG 0 Commission Representative: GINJ ❑ Op Shutdown 0 Abandoned ❑ 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name: Stan W.Golis 777-8356 Contact Name: Dan Marlowe Authorized Title: Operations Manager Contact Email: dmarlowe@hilcoro.com Contact Phone: 907-283-1329 Authorized Signature: gif Sys n /�,ot�s Date: 7 ✓/�7 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 311 - 3r`7 Plug Integrity 0 BOP Test Mechanical Integrity Test ❑ LocationcaClearance 0 Other: % J�� Pct F-jC)F' � I .2. 00 (fit �y.1i�.tit,A4Z- i t7SCVao 'CL. Post Initial Injection MIT Req'd? Yes El No 0 RBDMS �� JUL 1 1 2017 Spacing Exception Required? Yes ❑ No ®' Subsequent Form Required: k0 �o �. APPROVED BY f� Approved by: � II COMMISSIONER THE COMMISSION !� Date: I� C4 ��,pr 7 I7 sl› 1/s t"1 , ^ Submit Form and V ' Omn 10-403 Revise 4/2017 Approved application is vali rprninATitle at of approval. Attachments in Duplicate • • S Well Work Prognosis Well: D-20 Hilcorp Alaska,LLC Date: 07/05/17 Well Name: D-20 API Number: 50-733-20203-00 Current Status: Oil producer(ESP) Leg: Leg#: B-1 (SE) Estimated Start Date: July 15, 2017 Rig: Moncla 404 Reg.Approval Req'd? 10-403 Date Reg.Approval Rec'vd: Regulatory Contact: Juanita Lovett 777-8332 Permit to Drill Number: 169-095 First Call Engineer: Dan Marlowe (907) 283-1329 (0) (907) 398-9904 (M) Second Call Engineer: Stan Golis (907) 777-8356 (0) Current Bottom Hole Pressure: 3,438 psi @ 8,955'TVD 0.384 lbs/ft(7.38 ppg) Maximum Expected BHP: 3,438 psi @ 8,955'TVD 0.384 lbs/ft(7.38 ppg) Maximum Potential Surface Pressure: 2,542 psi Using 0.1 psi/ft gradient 20 MC 25.280(b)(4) This is a no-flow well 04/15/2017 with a SITP of 120 psig Brief Well Summary: The D-20 well is currently completed with a failed ESP installed March 2017.This work over will replace the combo Gas-Lift/ESP completion to restore productivity. Last Casing Test: 02/28/2015 at 9,461'to 2,500 psig for 30 minutes on chart ./ Procedure: 1. MIRU Moncla Rig#404. 2. Circulate hydrocarbon off of well.Work over fluid will be FIW. BOP's will be closed as needed to circulate the well. 3. ND Wellhead, NU BOP and test to 250psi low/3,000psi high/2,500 psi annular. (Note: Notify AOGCC 48 hours in advance of test to allow them to witness test). 4. Monitor well to ensure it is static. 5. Unseat hanger and POOH with completion. 6. PU and RIH with new combo gas-lift/ESP assembly. t/ 7. Set BPV. NU tree,test same. 8. Turn well over to production 9. Schedule SVS testing with AOGCC as per regulations. Attachments: 1. Well Schematic Current 2. Well Schematic Proposed 3. Wellhead Schematic Current/Proposed (Same) 4. BOP Drawing 5. Fluid Flow Diagrams 6. Moncla Rig 404—BOP Test Procedure 7. RWO Sundry Revision Change Form H . •� Trading Bay Unit SCHEMATIC Well: D-20 PTD: 169-095 API:50-733-20203-00 Hileorp Alaska.l,Lf. Completed: 03/30/2017 RKB to TBG Head=41.8' CASING DETAIL SIZE TYPE WT GRADE CONN ID TOP BTM. < r A" L 33" Conductor Surf 400' \�� 13-3/8" Surf Csg 61 K-55 Seal Lock 12.515 Surf 3,006' ;° 40 N-80 Butt 8.835 Surf 4,390' „. "; 9-5/8" Prod Csg 43.5 N-80 Butt 8.755 4,390' 6,156' : 5 95 Butt 6,156' 7,080' tir. 47 AR-95 Seal Lock 8.681 7,080' 9,674' q 6 /. ti 7-5/8" Tie-Back 29.7 L-80 SLID-II 6.875 Surf 9,467' �3.. f: Lr,� 7" Liner 29 N-80 Butt 6.185 9,463' 10,480' l iii �f' TUBING DETAIL Butt.; 31/2" 9.2# L-80 Supermax 2.992 Surf 9,036' iii :y�:; .......7„1„ . iii i: :▪r' JEWELRY DETAIL .4,-, iii ▪r Depth Depth 'ir1-9. �' NO (MD) (ND) ID OD Item al DV Collar 5,204' Tubing hanger: FMC-TC-ESP,NS-CT lift&susp,300-4 seal 32.70' 32.70' 2.992" 11.000" pocket,w/3"Type'H'BPV profile,2-3/8"CCL,alloy material 1 2,305' 2,249' 2.867" 5.968" GLM#1-SFO-2 2 4,154' 3,989' 2.867" 5.968" GLM#2-SFO-2 ""' 3 5,502' 5,278' 2.867" 5.968" GLM#3-SFO-2 NA 4 6,254' 5,991' 2.867" 5.968" GLM#4-SFO-2 o 10 4 6,773' 6,489' 2.867" 5.968" GLM#5-SFO-2 G-2 6 7,328' 7,011' 2.867" 5.968" GLM#6-SFO-2 ,- , 7 7,847' 7,501' 2.867" 5.968" GLM#7-SFO-2 moo ; oLL .. `., 8 8,368' 8,000' 2.867" 5.968" GLM#8-SFO-2 G-4 9 8,988' 8,594' 2.867" 5.968" GLM#9-SFO-2 p,.' 9,036' 8,639' - 5.130" Bolt on Discharge ' 9,037' 8,640' - 5.380" Tandem Pump section-Summit 190 stage SJ2800AR G-5 9,076' 8,677' - 5.130" Intake 10 9,080' 8,681' - 5.130" Tandem Seals-BPBSL tn. g Shoe 660 DIL 9,098' 8,698' - 5.620" Motor-Summit KMS2 500HP/3265V/80A e g' 2 S,- : • • Trading Bay Unit • ti Well: D-20 PROPOSED PTD: 169-095 API: 50-733-20203-00 IliilcorpAlaska,LL( Completed: FUTURE RKB to TBG Head=41.8' CASING DETAIL SIZE TYPE WT GRADE CONN ID TOP BTM. Vy 1 33" Conductor Surf 400' ,,' 13-3/8" Surf Csg 61 K-55 Seal Lock 12.515 Surf 3,006' ;a. 40 N-80 Butt 8.835 Surf 4,390' A '"' 43.5 N-80 Butt 8.755 4,390' 6,156' 1. 9-5/8" Prod Csg 5-95 Butt 6,156' 7,080' r 1f�^ 47 AR-95 Seal Lock 8.681 7,080' 9,674' .... 7-5/8" Tie-Back 29.7 L-80 SLID II 6.875 Surf 9,467 • {{.j 7" Liner 29 N-80 X-Line 6.185 9,463' 10,480' r ' tir TUBING DETAIL Butt:r 31/2" 9.2# L-80 Supermax 2.992 Surf ±9,050' ' p3r a of y %.. JEWELRY DETAIL yf:: .. ~ 1-9 di NO (MD) (ND) ID OD Item DV Collar 5,204' 32.70' 32.70' 2.992" 11.000" Tubing hanger: FMC-TC-ESP,NS-CT lift&susp,300-4 seal pocket,w/3"Type'H'BPV profile,2-3/8"CCL,alloy material f 1 ±2,306' ±2,250' 2.867" GLM#1 % Fi 2 ±4,165' ±4,000' 2.867" GLM#2 fi 3 ±5,526' ±5,300' 2.867" GLM#3 4 ±6,263' ±6,000' 2.867" GLM#4 29 105 ±6,784' ±6,500' 2.867" GLM#5 F'' t,-2 6 ±7,316' ±7,000' 2.867" GLM#6 g 7 ±7,846' ±7,500' 2.867" GLM#7 8 _ ±8,368' ±8,000' 2.867" GLM#8 G-4 9 ±9,000' ±8,605' 2.867" GLM#9 Bolt on Discharge $', - Pump -G-5 Intake 10 - Seals • ; Csg Shoe @ 9660'DIL - Motor(s) o 8$m i • • ±9,135' - Gauge(Zenith)/Centralizer/Anode ,,n,. t 10,068' 9,615' 3.250 Baker Model"0"Pkr. 12 10,078' 9,624' 2.750 Otis"X"Nipple,size 2.75 10,086' 9,632' 3.000 Bell Guide HK-1 10,198' 9,737' 3.250 Baker Model"D"Pkr. 13 10,206' 9,745' 2.625 Otis"Q"Nipple,size 2.625 10,212' 9,750' 3.000 Mule Shoe -1 K-3 PERFORATION DETAIL Zone Top(MD) Btm(MD) Top Btm(ND) Amt. SPF Last Perf Date Present Condition Fill tagged (TVD) ., on n03/18/15@10,045' , K-4 G-2 9,370' 9,388' 8,955' 8,972' 18' 5 03/19/2015 Open ' C3' G-2 9,421' 9,445' 9,004' 9,026' 24' 6 03/29/2017 G-4 9,478' 9,484' 9,057' 9,063' 6' 5 03/19/2015 Open G-5 9,610' 9,627' 9,182' 9,198' 17 5 03/19/2015 Open 12 Sqz 9,680' 9,681' 9,248' 9,249' 1' 4 11/02/1969 Sqz 100 sx cmt. Sqz 9,750' 9,751' 9,315' 9,315' 1' 4 10/30/1969 Sqz 75 sx cmt. r . HK-1 9,820' 9,885' 9,381' 9,442' 65' 20 06/15/1992 Open f/Production HK-1 9,828' 9,862' 9,388' 9,420' 34' 5 03/19/2015 Open d m •, HK-3 9,905' 9,950' 9,461' 9,503' 45' 16 06/15/1992 Open f/Production HK-4 9,908' 9,932' 9,464' 9,486' 24' 5 03/19/2015 Open 8/2 fitagged HK-4 9,950' 10,065' 9,503' 9,611' 115' 16 06/15/1992 Open f/Production nree@l0,zoo, r HK-5 4 • • • • • • HK-4 9,964' 9,986' 9,516' 9,537' 22' 5 03/19/2015 Open il:. 'it ' HK-510,070' 10,190' 9,616' 9,730' 120' 16 Jul-75 Open f/Production th °n 1 during tbg ru pkr.tluring � 13 HK-6 10,230' 10,260' 9,767' 9,796' 30' 4 Jul-75 Open f/Production WO 911-981 ... .' Brief Details&Info:To date ' U Spudded D-20 on 9/20/69.TD @ 10,506'on 10/25/69.Completed&RR on 11/06/69. 5,, •Hole Section MINT: •Approximate Rotating hrs: o 17-1/2"to 3050' 9.9 to 10 ppg o 33" 60 hrs 0 12-1/4"to 9,748' 9.8 to 10 ppg o 13-3/8" 285 hrs K-g o 8-1/2"to 10,506 0 9-5/8" 51 hrs 0 7" 16 hrs A 4/29/75 D-27 collided w/D-20 while drilling 17-1/2"surface hole.Communication to Inlet.Spotted 500sx of G cmt @ 400' PBTD=10,430' TD=10,5 in D-27.Possible length of breach in 13-3/8"is 1488'to 1497'.Penetration in D-20 9-5/8"@ 1497'. MAX HOLE ANGLE=21°,@ 2100' 7/75 WO sqz'd 9-5/8"csg @ 1497'4x.Total cmt placed 650 sx. Updated: 07/05/17 by DEM • • Dolly Varden Platform D-20 Proposed 12/19/2014 Hilrnrlr tl ieka_LTA. Dolly Varden Tubing hanger,FMC-TC-ESP, D-20 11 X 3 h NS-CT lift and susp, 13 3/8 X 9 5/8 X 7 5/8 X 300-4 seal pocket,w/3" 2 7/8 Type H BPV profile,2-3/8 CCL,Alloy material BHTA,Bowen,3 1/8 5M FE X 3" Bowen Quick Union ni n sas. M. Valve,swab,WKM-M, '' 31/85MFE,HWO' a T-24 `c t- G®C Valve,WKM-M,3 1/8 5M FE,w/ .,IWO En 15"OMNI operator Valve,wing,WKM-M, - -A- l� 2 1/16 5M FE,HWO, I l of � ® z T-24 a o'o C i Valve,lower master,WKM-M, r� 3 1/8 5M FE,HWO,T-24 y :n 1-61 unI Adapter,FMC-A-S-EC,11 SM 111 'III rotating flange x 31/8 5M rotating top,300-4 pocket prep,2-CCL ports,3.266 centers Multibowl wellhead assy, Ilf! —.- .E; .. c, tCactus MBS-2 Valve,WKM-M,2 1/16 SM FE, 135/83Mx115M,w/4- �II�= HWO DD 21/16 5M SSO,prepped for , _ i 7 5/8 mandrel hanger,and lilk, � tubing hanger,9 5/8 HPS : �l' _ �II I f•�4 11 bottom ii I' p Valve,WKM-M,21/16 SM FE, i HWO,DD i , 1alga o l 11.10,-1- _ ' _ 2 - 1ti I ., = _. ill Casing head,CIW-WF, : 1 _, 1.1 Valve,CIW-F,2 1/16 3M FE, 13 5/8 3M X 13 3/8 casing fi HWO,AA trim thread bottom,w/2-2 1/16 = c , - 4 SM EFO 1�� n 11111111111191.111611i'19E e f . la • s Dolly Varden Platform Moncla BOP 12/19/2016 Hilenrp ilarika_1.IA III lb: 4.54' 4119 G00alililiilit ill I11 I!Ia E. E. Variable rams — j sl:.iiii i �'r �-I _ �O 2 7/8-5 4.67' _-01111 I 13 5/8-5000 ®_ Blind Rams 11111 - ii1 iii lit lit Ill Choke and Kill valves -� 21/165M F_r►. Oil III Ill III II I 11 2.26' : • .�.,, . _, 1C�u i Cross! ' do- 41/165MEFOl1� Itill(jJ t j CSI Riser 13 5/8 5M FE X 13 5/8 5M FE 111111111- II ill III Iii 111,III-III Spacer spool 135/85M FEX115M ill lii Ill iii III `a C o U • p O 0 (Jou OOUO O u p V O D U 0 U U 0 0 o • N m V V1 ,c-,- N M V l0 N as 01 2 nnnnn c 2 p UUUUUUUVU O .-1 N M V L.0 al .-I N rn V 1-1 t0 N 00 01 CO -o a -o a s o -o -o a a a a a 0 0 0 0 0 t o 0 0 o a o 0 0 0 o w - - - - - N > J y C C C G C C C Cy0 L ) Hifi C C C E E E v a, ar y w w CU ar a 0 a✓ >> E J � z o Lrttt000oa. v _ =YU L t t r L L L L Le > d d C 1 [l Y = U UUVVVUUVUUvR . a a Y o 0 -a o o LL C C L C of U Kao O 4 4 N Q) 4 r . 00 mak- - in. 00 . �k- U w 0 W Y <Y CO N) . � . ZO H re O cc w o Y> ss1— Milli m CL 0 TQ [3 F- U) W Ha jOS r z O o Z w aDz CO oa Jcn_i I— ❑ a ■ Z • Z oCLOOI- � O � ZQ QQv)- � • w U J Jw C 2D0 > r H- N w J O Z w Mo 0, ¢1 Y LL Z Hoo 7 m z Q :L.LQ J p o OW N LL U 0 Y p OUOUQ O O u O OJOUOUUOUU 0 0 a _ ..N N V t0 I, N P 2 22222 5 u 22222 UUUUUUUUUo N M Cr V1 OJ rl N M V vl 0) n Da O1 N "O 'O 9 'O 'O p -O 'O 'O 'O 'a a U 'O 'O if 0 0 0 U N 0 0 0 0 0 0 0 0 0 0 w a a n a n cr. ar E E E E E _ = u 0 0 0 0 0 0 0 0 0 0 o n L L L L L L L L L L L =1 co 2 2 2 2 2 Y Y M U U U U U U U U U U U vz N o C ® a Y 2 o n uc - c 1,41 14 N O) N - co mak' ' V!) . CO mak' ' U w 11X LU Q a 0) .. 't , z O N U 2 U N w c[ _ O cc O a0 w as w m " m F m _ co W a H • Q z co Q -J D z Z o Z w Qaz Q J U)J Z d . — c Q tYU o O } � E w z 0 JOOmO ' � • J J D J D4 D4 fC • J O O <w a My E.0.0, ¢N Y LL Z 0 4 ,=, o 0S' z m Q 0 F- Z O 5 J Q '� ' DQ • O D 0 fY 0 • • Moncla Rig 404 BOP Test Procedure Hilcorp Alaska,LLC Attachment#1 Attachment #1 Hilcorp Alaska, LLC - BOP Test Procedure: Moncla Rig 404, WO Program — Oil Producers, Water Injectors Pre Rig Move 1) Blow down well, bleed gas to Well Clean Tank that is vented thru flare to atmosphere 2) Load well with FIW to kill well. • Note: Fluid level will fall to a depth that balances with reservoir pressure. 3) Shoot fluid level at least 24 hours before moving on well. 4) Shoot fluid level again,right before ND/NU. Confirm that well is static. Initial Test(i.e.Tubing Hanger is in the Wellhead) If BPV profile is good 1) Set BPV. ND Tree. NU BOP. 2) MU landing joint. Pull BPV. Set 2-way check in hanger. 3) Space out test joint so end of tubing(EOT)is just above the blind rams. 4) Set slips,mark same. Test BOPE per standard test procedure. If the tubing hanger won't pressure test due to either a penetrator leak or the BPV profile is eroded and/or corroded and BPV cannot be set with tree on. Profile and/or landing threads must be prepped while tree is off.Worst Case: BPV profile and landing threads are bad. 1) Attempt to set BPV through tree. If unsuccessful,shoot fluid level. 2) If fluid level is static from previous fluid level shots, notify Hilcorp Anchorage office that the well is static and the tree must be removed with no BPV.As approved in the sundry, proceed as follows: a) ND tree with no BPV b) Inspect and prepare BPV profile to accept a 2-way valve,or prepare lift-threads to accept landing joint to hold pressure. If well is a producer and the culprit is scale, attempt to clean profile with Muriatic acid and a wire brush or wheel. c) Set 2-way check valve by hand,or MU landing(test)joint to lift-threads d) For ESP wells-Ensure that cap is on cable penetrator e) NU BOP. Test BOPE per standard procedure. 3) If both set of threads appear to be bad and unable to hold a pressure test and/or a penetrator leaks, notify Operations Engineer(Hilcorp), Mr. Guy Schwartz(AOGCC)and Mr.Jim Regg(AOGCC)via email explaining the wellhead situation prior to performing the rolling test. AOGCC may elect to send an inspector to witness. As outlined and approved in the sundry, proceed as follows: a) Nipple Up BOPE b) With stack out of the test path,test choke manifold per standard procedure c) Conduct a rolling test: Test the rams and annular with the pump continuing to pump, (monitor the surface equipment for leaks to ensure that the fluid is going down-hole and not leaking anywhere at surface.) d) Hold a constant pressure on the equipment and monitor the fluid/pump rate into the well. Record the pumping rate and pressure. e) Once the BOP ram and annular tests are completed,test the remainder of the system following the normal test procedure(floor valves,gas detection,etc.) • • Moncla Rig 404 BOP Test Procedure Hilcorp Alaska,LLC c Attachment#1 f) Record and report this test with notes in the remarks column that the tubing hanger/BPV profile/ penetrator wouldn't hold pressure and rolling test was performed on BOP Equipment and list items, pressures and rates. 4) Pull hanger to surface. (Requires tubing cuts as necessary to free tubing). CBU to displace annulus and tubing with kill weight fluid. 5) If a rolling test was conducted, remove the old hanger, MU new hanger or test plug to the completion tubing. Re-land hanger(or test plug)in tubing head. Test BOPE per standard procedure. Subsequent Tests(i.e.Test Plug can be set in the Tubing-head) 1) Remove wear bushing. a) Use inverted test plug to pull wear busing. MU to joint of tubing. b) Thread into wear bushing c) Back out hold down pins d) Pull and retrieve wear bushing. 2) Break off test plug and invert same-RIH with test plug on joint of tubing. Install a pump-in sub w/test line plus an open TIW or lower Kelly valve in top of test joint w/open IBOP. 3) Test BOPE per standard procedure. STANDARD BOPE TEST PROCEDURE(after 2-way check or test plug is set) 1) Fill stack and all lines with rig pump-install chart recorder on test line connected to pump-in sub below safety valve and IBOP in test joint assembly. 2) Note: When testing, pressure up with pump to desired pressure,close valve on pump manifold to trap pressure and read same with chart recorder(test pressures will be indicated in Sundry). 3) Referencing the attached schematics test rams and valves as follows. a) Close 15t valve on standpipe manifold,close valves 1, 2, 10 on choke manifold and close the annular preventer,open safety valve on top of test jt and close IBOP. Pressure test to 250 psi for 5 minutes and 2,500 psi high for 5 minutes. If passes after 5 minutes on each, bleed off pressure back to tank and open annular. b) Close pipe rams and open annular preventer,close safety valve and open IBOP on test joint,close outside valve on kill side of mud cross, open 1st valve of standpipe, close valves 3,4&9 on choke manifold,open valves 1&2 on choke manifold. Test to 250 psi for 5 minutes and 3,000 psi high for 5 minutes. If passes after 5 minutes on each, bleed off pressure back to tank. c) Test Dual Rams. If the well has dual tubing,and dual rams are installed in the stack,test the dual rams by picking up two test joints with dual elevators and lowering them into stack and position them properly in the dual rams. Close rams. Test to 250 psi for 5 minutes and 3,000 psi for 5 minutes. If passes after 5 minutes on each, bleed off pressure back to tank. d) Close inside valve/open outside valve on kill side of mud cross, close valves 5&6/open valves 3&4 on choke manifold. Test to 250 psi for 5 minutes and 3,000 psi for 5 minutes. If passes after 5 minutes on each, bleed off pressure back to tank. e) Close manual and super choke/open valves 5&6 on choke manifold. Pressure up to 1200 psi and bleed off 200—300#s recording change and stabilization. If passes after 5 minutes, bleed of pressure back to tank. f) Close HCR(outside valve on choke side of mud cross), open manual&super choke. Test to 250 psi for 5 minutes and 3000 psi for 5 minutes. If passes after 5 minutes on each, bleed off pressure back to tank. • . Moncla Rig 404 BOP Test Procedure Hilcorp Alaska,LL€ Attachment#1 g) Close inside valve/open outside valve(HCR)on choke side of mud cross. Test to 250 psi for 5 minutes and 3000 psi for 5 minutes. If passes after 5 minutes on each, bleed off pressure back to tank. h) Ensure all pressure is bled off-open pipe rams and pull test joint leaving test plug/2-way check in place. Close blind rams and attach test line to valve 10 on choke manifold,close valve 7&8/open valve 10 on choke manifold. Test to 250 psi for 5 minutes and 3000 psi for 5 minutes. If passes after 5 minutes on each, bleed off pressure back to tank. i) Test additional floor valves(TIW or Lower Kelly Valve)and IBOPs as necessary. STANDARD TEST PROCEDURE OF CLOSING UNIT(ACCUMULATOR) 1) This is a test of stored energy. Shut off all power to electric and pneumatic pumps. 2) Record "Accumulator Pressure". It should be+/-3,000 psi. 3) Close Annular Preventer,the Pipe Rams, and HCR. Close 2nd set of pipe rams if installed (e.g.dual pipe rams). Open the lower pipe rams to simulate the closing volume on the blinds. 4) Allow pressures to stabilize. 5) While stabilizing: Record pressure values of each Nitrogen bottle and average over the number of bottles. (i.e. Report might read "10 bottles at 2,150 psi"). 6) After accumulator has stabilized, record accumulator pressure again. This represents the pressure and volume remaining after all preventers are closed. (The stabilized pressure must be at least 200 psi above the pre- charge pressure of 1,000 psi). 7) Turn on the pump and record the amount of time it takes to build an additional 200 psi on the accumulator gauge. This is usually+/-30 seconds. 8) Once 200 psi pressure build is reached,turn on the pneumatic pumps and record the time it takes for the pumps to automatically shut-off after the pressure to builds back to original pressure(+/-3,000 psi). Note: Make sure the electric pump is turned to"Auto", not"Manual"so the pumps will kick-off automatically. 9) Open all rams and annular and close HCR to place BOPE back into operating position for well work. 10) Fill out AOGCC report. FINAL STEP,FINAL CHECK 1) Test Gas Alarms 2) Double check all rams and valves,for correct operating position 3) Fill out the AOGCC BOPE Test Form (10-424)in Excel Format and e-mail to AOGCC and Juanita Lovett. Document both the rolling test and the follow up tests. , � • 0 = mar m .? ea F) ❑ > Ce C o ai t. CU a) E 0o ° ca U U Q Qa C N Q E ... • m U `"' a1 N a) a) > ,73 N 2 Q E Q L• •- D• a) • m m N O 7-0 Q Q-m O 21.L ci • CT ca a� L M Q t% Kt L Z of ca ❑ ❑ �L d d} C U Z 0‘ m N L a, U i o ° w o Co13 > o O Q. as d. O C L a) ❑ L cc 3 (a • a a) coo 0 0 1- Ci)y :1.6. a�iO -a) cb d EL t) > c n - 2 0 - a o - m Q. a L 0 c — as as c �� c c 4 5 0) Cl) cop Cl) Lu C N G1 0 > w 0 c U 0. aQaca Q- aL •czt, 0. • > O m 4 �+ 0 as ` E 0 co c Q m X S 3 0) H �a - — a) X cn .Q' as m 0 � ,..z C 0 o a) a N Cl) 0a It S--1 rii .moi Qo 0 — O 0ox ; cp co (U iCl) < a Q a STATE OF ALASKA ALL OIL AND GAS CONSERVATION COMM ION REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon U Plug Perforations U Fracture Stimulate U Pull Tubing U Operations shutdown U Performed: Suspend ❑ Perforate 0 Other Stimulate ❑ Alter Casing ❑ Change Approved Program ❑ Plug for Redrill ❑ erforate New Pool ❑ Repair Well ❑ Re-enter Susp Well 0 Other: Combo BUESP Completion0 2.Operator 4.Well Class Before Work: 5.Permit to Drill Number: Name: Hilcorp Alaska,LLC Development 0 Exploratory 0 169-095 3.Address: 3800 Centerpoint Dr,Suite 1400 Anchorage, Stratigraphic❑ Service ❑ 6.API Number: AK 99503 50-733-20203-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL0018729 Trading Bay Unit/D-20 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): N/A McArthur River Field/Middle Kenai G and Hemlock Oil Pools 11.Present Well Condition Summary: Total Depth measured 10,506 feet Plugs measured N/A RECEIVED true vertical 10,028 feet Junk measured 10,068&10,198 feet APR 2 5 2017 Effective Depth measured 10,045 feet Packer measured 10,068&10,198 feet H[ u true vertical 9,593 feet true vertical 9,615&9,737 feet . 0 Casing Length Size MD TVD Burst Collapse Structural Conductor 400' 33" 400' 399' Surface 3,006' 13-3/8" 3,006' 2,905' 3,090 psi 1,540 psi Production 9,674' 9-5/8" 9,674' 9,242' 5,750 psi 3,090 psi Liner 9,467' 7-5/8" 9,467' 9,047' 6,890 psi 4,790 psi Liner 1,017' 7" 10,480' 10,003' 8,160 psi 7,020 psi Perforation depth Measured depth 9,370-10,260 11/ tzl True Vertical depth 8,955-9,796 )111/41° 10 I Tubing(size,grade,measured and true vertical depth) 3-1/2" 9.2#/L-80 9,036'MD 8,639'TVD Packers and SSSV(type,measured and true vertical depth) Model"D"Pkrs 10,068'&10,198'MD 9,615'&9,737'TVD SSSV 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: SCANMED AVERY I ° l..U!6 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 135 47 734 110 120 Subsequent to operation: 235 59 2350 110 120 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations 0Exploratory0 Development 0 Service❑ Stratigraphic 0 Copies of Logs and Surveys Run 0 16.Well Status after work: Oil ❑✓ Gas ❑ WDSPL❑ Printed and Electronic Fracture Stimulation Data 0 GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP 0 SPLUG❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: 316-642&317-033 Authorized Name: Stan Golis 777-8356 Contact Name: Dan Marlowe Authorized Title: Operations ManagerContact Email: dmarlowe@hilcorp.com Authorized Signature: (A311/14•:# Date: 4 1 Ls/to(? Contact Phone: 907-283-1329 )4 c// 4' r, Form 10-404 Revised 4/2017 ik 7 RDDiWIS L�MAY - 3 2017 Submit Original Only • • Hilcorp Alaska, LLC Well Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date D-20 Moncla 404 50-733-20203-00 169-095 3/26/17 3/31/17 Daily Operations: 03/26/17-Sunday Moved equipment in path of skid and setup jacks for West skid. Skidded rig carrier(with derrick standing) from D-12RD West to being inline w/ D-20. Setup Dolly pancake jacks. Skid rig carrier South centering block over D-20 well bay(had to trouble shoot hyd power unit then R/U assist using (2) port-a-powers to secure pancake jacks in place). Production shut down D-20 and locked opened SSSV and packer vent valve. Bleed down well. R/D cylinder and pancake jacks and removed same from drill deck. R/U rig pump to circulate well. Presently flushing well using FIW @ 2 BPM 300 psi taking returns to well-clean tank. Once we've pumped 600 bbls (6:15) we'll shut down pump and monitor well. We have set heater and koomey in place- M/U koomey lines-slide racking mat into place-set stairs to carrier- M/U carrier stabilizer cables. 03/27/17- Monday Continued flushing oil &gas from well using FIW at 2 BPM 420 PSI. Wasn't cleaning up (oil still in returns- most probably because of limited returns from restriction in vent valve). Shutdown pump-tb on vacuum, slight oil push from annulus (no pressure on gauge). NOS rep set BPV. NOS rep and production worked control lines and power cable. N/D tree. Cleaned threads and ring groove- ran in lock down pins to stop small leak- installed blanked test sub w/3 1/2" NS-CT x-over in hanger (threads look good). N/U 13 5/8" 5M riser w/ 11" 5M adapter on btm, 13 5/8" mud cross w/ HCRs & manual valves, 13 5/8" double gate w/ blinds and 2 7/8" x 5"VBR and 13 5/8" annular preventer. Moved choke house, electrical panel, test pump and walkway across double beams w/stairs into position. Put heat to choke house, koomey unit, test pump, swaco unit and dog house. Mounted rig floor-setup stands and windwalls. Ran koomey, choke and kill lines to stack. RKB strap= 32.7',Wrapped BOPE and carrier. Run heat to choke house, koomey and BOPE. Setup tongs and handling equipment on rig floor. Work M/V Resolution. M/U 3-1/2" test joint with NOS x-over to blanking sub on bottom, pumpin, safety valve and IBOP on top. R/U test pump. Load BOPE with FIW. Open casing valve to well-clean tank- 1 bbl oil flowed back to tank then NO FLOW. Shell test BOPE 3500 psi. Leaked at hold-down pins and 13-5/8" 5M X 11" 5M flange.Tighten same. Pressured back up(,. for a good 3500#test.Tested all BOPE 250 PSI low 3500 PSI high as per Hilcorp and AOGCC requirements. Performed abet-c, successful Koomey draw down test. Witness waived by Mike Quick/AOGCC 10:07 AM 3/27/17 by email. Pulled 2-7/8" test <e, joint and test sub. B/O hold-down pins, left 4 engaged. Pull BPV. M/U 3-1/2" landing joint w/safety valve & pumpin. • • Hilcorp Alaska, LLC Well Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date D-20 Moncla 404 50-733-20203-00 169-095 3/26/17 3/31/17 Daily Operations: 03/28/17-Tuesday Backed out remaining hold-down pins and pulled on production string unseating hanger at 75k and pulling pkr loose at 130k. Pulled hanger into 13 5/8" riser and closed annular. Lined up to flush well w/ FIW sending returns to TBF (NPFT sent). Began pumping 2 BPM 0 PSI-30 bbls in pressure started increasing. 0930 hrs pressure leveled off at 304 PSI - no returns. Tied into annulus and pumped 11 bbls- pressured up- unable to pump past released pkr(vent valve not pressured open),Worked pkr and attempted again- nogo. Tied back into well clean tank. R/U Summit pulling equipment. Checked tb-static, casing had slight oil flow-attempted to pump past released pkr again with no success. Opened casing line to well clean tank and choke side to rig tank. Pulled hanger to surface (watching fluid level) and plumbed control line to vent valve port-slacked hanger down and closed annular-opened vent valve. Bullheaded 300 bbls FIW down annulus at 2 BPM 0- 294#s. Open annular. Pull tubing hanger to surface and worked same- laid down 3-1/2" landing joint and tubing hanger, L/D 3 joints of 3-1/2" Supermax(SPM).Tie back power cable &flat pack to Summit spoolers. L/D 5 joints of 3-1/2" SPM. L/D 3-1/2" SPM pup, SSSV, 3-1/2" SPM b X 3-1/2" BTC p and 3-1/2" BTC b x 2-7/8" 8rd pup. L/D 2-7/8" 8rd pup and 7-5/8" Dual ESP Packer assy. L/D 2- 7/8" 8rd pup, X-nipple, pup, 2-7/8" 8rd b x 3-1/2" BTC p and 3-1/2" BTC b X 3-1/2" SPM p. L/D 4 joints 3-1/2" SPM (12 total). S/B stands in derrick. Pump 5 bbls. FIW every 10 stands. Load hole with FIW. Pumped 121 bbls (3394 stks). Continue racking back stands. Pump 10 bbls. FIW every 20 stands. 72 of 132 stands in derrick at report time. • • Hilcorp Alaska, LLC Well Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date D-20 Moncla 404 50-733-20203-00 169-095 3/26/17 3/31/17 Daily Operations: 03/29/17-Wednesday Continued POOH w/recovered ESP/SPM production string pumping 10 bbls every 20 stands. 0630 hrs changed out Summit fJ power cable reel. 4 stands OOH began noticing that flat pack shealthing began disintegrating to the point of being completely gone- pieces found under clamps would crumble up in your hand. Ordered junk basket/gauge ring to run on ELine. 132 stands OOH (at ESP assy). Filled hole while holding procedure meeting on pump disassembly. Cut power cable and",o' flat pack lines-tied them off to derrick. Raised assy as high as possible and inspected same-found one small hole (about the size of the end of your thumb) in upper pump section. Lowered it back in hole and began disassembly. Continued BJ ESP found 2nd smaller hole in 2nd pump. Upper and lower seal sections checked normal- motor checked normal- no obvious problems w/seals or motor. Cleared and cleaned floor- moved equipment around to spot Pollard ELine unit. R/U Pollard ELine. RIH with GR/CCL,Junk basket and 6.65" GR. Wire fall slowed at 1600'. Continue TIH as fall rate allows. Set down at 9461' WLM (uncorrected). POOH with slight overpulls off bottom. Return to surface with 3 larger pieces and 1 smaller piece flatpack and 1 piece o-ring seal. Pump 10 bbls. FIW on the hour every hour. RIH ELine with GR/CCL,Junk Basket and 5.98" GR. Set down at 9851' (corrected). Work wire 4 times, no pass. PUH for logging pass. POOH. Return to surface with empty junk basket and 2 new marks on bottom of 5.98" GR. OOH. L/D Junk Basket& GR. P/U Gun#1 (14'X 4.50" GeoDynamics, 6 SPF, 60 deg phase). PT= 1000 psi,good test. RIH Eline with GR/CCL (7.50' GR/CCL to top shot) and 14' perf gun to 9508' MD CORRECTED. Pull correlation pass 9508' -9231'. Send LAS file of correlation pass to HAK geologist for depth correction & correlation verification. R/U Summit spoolers with power cable &flat pack spools. Correction/correlation verified. RIH, pull up logging to place shots on depth, GR/CCL= 9423.5'. Fire Gun#1, penis 9431' -9445'. POOH. L/D Gun#1. Shots fired. P/U Gun#2 (10' X 4.50" GeoDynamics, 6 SPF, 60 deg phase). RIH with GR/CCL(7.50' GR/CCL to top shot) and Gun#2 to 9510'. Pull up for correlation log 9510' -9217'. RIH to 9445', PUH to place shots on depth. GR/CCL= 9413.5'. Fire Gun#2, perf 9421' -9431'. RIH with spent Gun#2 (OD^ 4.60") to 9994'. POOH. L/D Gun#2. R/D ELine. 4 P,41 OSP fr/ 03/30/17-Thursday Prepped rig floor w/equipment needed to run Summit ESP. Hung sheaves w/ power cable and flat pack. Pumping 10 bbls of FIW every hr. P/U 5.62" 500 HP motor and lowered it in hole w/gauge and centralizer- M/U cap to fill with oil and serviced motor-connected flat pack lines- M/U lower& upper tandem seal sections. 0930 hrs spliced in power cable and checked insulation. M/U intake, double pump sections, ported pressure sub, bolt on discharge and handling jt w/x-over sub. Cleared floor of unneeded equipment and prepped to run in ESP/SPM assembly on 3 1/2" 9.2# L-80 SuperMax (reused) tubing out of derrick. Filled hole w/88 bbls of FIW. Began RIH w/ ESP/SPM assy pumping 20 bbls FIW every 20 stands, clamping power cable and flatpack as needed.Test power cable every 1000'. RIH with Stand#51, GLM#7 hang up in BOPS. PU GLM to rig floor, Summit inspects, superficial damage to power cable armor shield.Test power cable-good test. Repair 4' section of armor shield, no damage or deformation to power cable rubber sheath. Call Operations Eng. (22:59)to inform and request allowance to move GLM#7 up hole 1 joint, request approved. B/O GLM#7, split Stand#51 across GLM, RIH. Continue RIH w/ ESP/SPM assy pumping 20 bbls FIW every 20 stands, clamping power cable and flatpack as needed.Test power cable every 1000'. 96 of 132 stands in the hole at report time.(6,680'). • • I Hilcorp Alaska, LLC Well Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date D-20 Moncla 404 50-733-20203-00 169-095 3/26/17 3/31/17 Daily Operations: , , d;--= . 03/31/17- Friday Continue RIH w/5.63" 500 HP double pump ESP assy w/GLMs on 3 1/2" 9.2# L-80 SuperMax tubing from 6,680' (96 stands) to 7,634'. Changed power cable reels and Summit spliced cable at 110 stands in hole which will put splice @ 7,774'. Tested- cable good. Continued in hole to 132 stands in = 9,097'. NOS rep M/U tb hanger-Summit built penetrator splice and plumbed same thru hanger- NOS plumbed control lines thru hanger. Slacked off, landing hanger w/86k down, est P/U 130k-end of pump at 9,134.07'. B/O landing jt and set BPV. Cleared rig floor of all Summit's equipment, hyd tongs and handling equipment. Cleaned rig tank sending fluids to well-clean tank(NPFT sent). Power down koomey. Blew down all lines and removed. L/D Summit sheaves, removed rig floor and carrier hooches. Scoped down and secured derrick. Broke all BOPE bolts prepping for N/D. N/D BOPE- power washed same. N/U tree. Plumb stainless chemical lines and power cable thru tree adapter. Summit tested ESP power cable -good test. NOS tested tubing pack-off void to 500 psi/5 mins, 5000 psi/15 mins- good test. NOS pulled BPV and set 2-way check. Tie-in chemical lines. Shell tested tree to 500 psi/5 mins, 5000 psi/15 mins- good test. Turned well over to production at 0500 hrs. Continued cleaning and organizing W/O equipment, platform deck and well bay area in preparation to be released from platform. • • Trading Bay Unit Well: D-20 illSCHEMATIC PTD: 169-095 API:50-733-20203-00 IliIcon)Alaska.LLC Completed: 03/30/2017 RKB to TBG Head=41.8' CASING DETAIL SIZE TYPE WT GRADE CONN ID TOP BTM. l 33" Conductor Surf 400' 13-3/8" Surf Csg 61 K-55 Seal Lock 12.515 Surf 3,006' R;+ 40 N-80 Butt 8.835 Surf 4,390' '" 43.5 N-80 Butt 8.755 4,390' 6,156' I::: 9-5/8" Prod Csg ya: 47 S-95 Butt 8.681 6,156' 7,080' ;ti f' AR-95 Seal Lock 7,080' 9,674' 0 1fµ, 7-5/8" Tie-Back 29.7 L-80 SLID II 6.875 Surf 9,467' yrs 7" Liner 29 N 80 X-Line 6.185 9,463' 10,480' ti 11'; TUBING DETAIL :r' 3-1/2" 9.2# L-80 Supermax 2.992 Surf 9,036' ;y. J .1f ti ,1f' JEWELRY DETAIL yi' a 11' ti 1 9 i NO (MD) (ND) ID OD Item DV Collar !B 5,204' Tubing hanger: FMC-TC-ESP,NS-CT lift&susp,300-4 seal 32.70' 32.70' 2.992" 11.000" ;; pocket,w/3"Type'H'BPV profile,2-3/8"CCL,alloy material 1 2,305' 2,249' 2.867" 5.968" GLM#1-SFO-2 2 4,154' 3,989' 2.867" 5.968" GLM#2-SFO-2 {'' 3 5,502' 5,278' 2.867" 5.968" GLM#3-SFO-2 {% 4 6,254' 5,991' 2.867" 5.968" GLM#4-SFO-2 a 104: 5 6,773' 6,489' 2.867" 5.968" GLM#5-SFO-2 G-2 6 7,328' 7,011' 2.867" 555.:999666888':': .968" GLM#6-- SFO-2 1! 7 7,847' 7,501' 2.867" 5.968" GLM#7-SFO-2 3 8 8,368' 8,000' 2.867" 5.968" GLM#8-SFO-2 G-4 9 8,988' 8,594' 2.867" 5.968" GLM#9-SFO-2 ,� 9,036' 8,639' 5.130" Bolt on Discharge s" }B 9,037' 8,640' - 5.380" Tandem Pump section-Summit 190 stage SJ2800AR ! G-5 9,076' 8,677' - 5.130" Intake t � 10 g 080' 8,681' 5.130" Tandem Seals-BPBSL cs. Csg Shoe 9,098' 8,698' - 5.620" Motor-Summit KMS2 500HP/3265V/80A @ 9660'DIL o g m Or cif • . 9,134' 8,732' - 5.620" Gauge(Zenith)/Centralizer/Anode 8 P s s = = 10,068' 9,615' 3.250 Baker Model"D"Pkr. i i' I'. . ' 12 10,078' 9,624' 2.750 Otis"X"Nipple,size 2.75 10,086' 9,632' 3.000 Bell Guide HK-1 10,198' 9,737' 3.250 Baker Model"D"Pkr. 13 10,206' 9,745' 2.625 Otis"Q"Nipple,size 2.625 10,212' 9,750' 3.000 Mule Shoe AHK-3 PERFORATION DETAIL v Zone Top(MD) Btm(MD) (TVD) Btm(TVD) Amt. SPF Last Perf Date Present Condition Fill tagged on 03/16/15 10,045' HK-4 G-2 9,370' 9,388' 8,955' 8,972' 18' 5 03/19/2015 Open ;:;:;:~3;:; G-2 9,421' 9,445' 9,004' 9,026' 24' 6 03/29/2017 0-4 9,478' 9,484' 9,057' 9,063' 6' 5 03/19/2015 Open ' 1111 I 0-5 9,610' 9,627' 9,182' 9,198' 17 5 03/19/2015 Open I 12 Sqz 9,680' 9,681' 9,248' 9,249' 1' 4 11/02/1969 Sqz 100 sx cmt. s L '---- Sqz 9,750' 9,751' 9,315' 9,315' 1' 4 10/30/1969 Sqz 75 sx cmt. i5Wok = HK-1 9,820' 9,885' 9,381' 9,442' 65' 20 06/15/1992 Open f/Production o 7- + = HK-1 9,828' 9,862' 9,388' 9,420' 34' 5 03/19/2015 Open o (�+ -� HK-3 9,905' 9,950' 9,461' 9,503' 45' 16 06/15/1992 Open f/Production ,, HK-4 9,908' 9,932' 9,464' 9,486' 24' 5 03/19/2015 Open --, 6/26/ggedon HK-4 9,950' 10,065' 9,503' 9,611' 115' 16 06/15/1992 Open f/Production 6/26/86 @ 10,201' HK-5 HK-4 9,964' 9,986' 9,516' 9,537' 22' 5 03/19/2015 Open HK-5 10,070' 10,190' 9,616' 9,730' 120' 16 Jul-75 Open f/Production No Joy on 21/16"tbg HK-6 10,230' 10,260' 9,767' 9,796' 30' 4 Jul-75 Open f/Production thru pk during '�(�J�! 13 WO In 11/63 " r Brief Details&Info:To date r ' Spudded D-20 on 9/20/69.TD @ 10,506'on 10/25/69.Completed&RR on 11/06/69. alow •Hole Section MINT: •Approximate Rotating hrs: 4' * o 17-1/2"to 3050' 9.9 to 10 ppg o 33" 60 hrs o 12-1/4"to 9,748' 9.8 to 10 ppg 0 13-3/8" 285 hrs K6 o 8-1/2"to 10,506 o 9-5/8" 51 hrs ::::....:..:..:: 0 7" 16hrs A 4/29/75 D-27 collided w/D-20 while drilling 17-1/2"surface hole.Communication to Inlet.Spotted 500sx of G cmt @ 400' N. in D-27.Possible length of breach in 13-3/8"is 1488'to 1497'.Penetration in D-20 9-5/8"@ 1497'. PBTD=10,430' TD=10,506' MAX HOLE ANGLE=21°,@ 2100' 7/75 WO sqz'd 9-5/8"csg @ 1497'4x.Total cmt placed 650 sx. Updated: 03/30/17 by DEM V OF Thr, • • c„i I//7 ‘v THE STATE Alaska Oil and Gas �,�►"s-d��, of \ LA S KA Conservation Commission ,.,t_=_ _`, 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 " Main: 907.279.1433 ALAS Fax: 907.276.7542 www.aogcc.alaska.gov April 19, 2017 Mr. Stan Golis Operations Manager—CI Offshore Hilcorp Alaska, LLC P.O. Box 244027 SCANNED APR 2 02017: Anchorage, AK 99524-4027 RE: No-Flow Verification Dolly Varden Platform, Trading Bay Unit D-20 PTD 1690950 Dear Mr. Golis: On April 15, 2017, an Alaska Oil and Gas Conservation Commission (AOGCC) Petroleum Inspector witnessed a no-flow test of Trading Bay Unit D-20. The well is operated by Hilcorp Alaska, LLC (Hilcorp). The AOGCC Inspector confirmed that the proper test equipment — as outlined in AOGCC Industry Guidance Bulletin 10-004 —was rigged up on Trading Bay Unit D- 20 prior to the test. The well performance was monitored for three hours with unmeasurable gas flow observed at the end of the flow monitoring periods. There was no liquid flow to surface during the no-flow test. The well may be produced without a subsurface safety valve. A fail-safe automatic surface safety valve system capable of preventing uncontrolled flow must be maintained in proper working condition in this well as required in 20 AAC 25.265. The subsurface safety valve must be returned to service if Trading Bay Unit D-20 demonstrates an ability to flow unassisted to surface. Any cleanout, perforating or other stimulation work in this well will necessitate a subsequent no-flow test. Please retain a copy of this letter at the Dolly Varden platform. Sincerely, \\Xt.wszt...Q.m.c.x- Michael Quick Sr. Petroleum Engineer cc: J. Regg P. Brooks AOGCC Inspectors • • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg Tg 5Irof -7 DATE: 4/15/2017 P. I. Supervisor l FROM: Adam Earl SUBJECT: No Flow Test Petroleum Inspector TBU D-20 Hilcorp Alaska LLC PTD 1690950 April 15, 2017: Traveled to the Dolly Platform to witness a NO-FLOW test on well D- 20. AOGCC inspector, Brian Bixby was also in attendance. We met up with lead operator Christy Anderson and went down to the well room to look over the well and the set-up configuration for the test. The tubing and I/A were married together at surface by - a 2" hardline jumper. This well is a packerless ESP. The following table shows test details: Time Pressures1 Flow Rate Remarks (psi) Gas - scf/hr Liquid - gal/hr 9:05 0/0/14 - 0 • 0 Well shut in 9:35 0.23/0.23/14 0 0 SI Opened well; 900scfh for 10:05 0.47/0.47/14 900 0 • 3sec then bled down quickly (90sec) before SI; 0.14psi Tbg and IA when SI 10:35 0.42/0.42/14 0 0 SI Opened well; 1000scfh for 11:05 0.65/0.65/14 1000 0 3sec then bled down quickly (180sec) before SI; 0.07psi Tbg and IA when SI 11:35 0.47/0.47/14 0 0 SI Opened well; 1000scfh for 12:05 0.71/0.71/14 1050 0 3sec then bled down quickly (180sec) before SI; 0.07psi Tbg and IA when SI Pressures are T/IA/OA Summary: I witnessed a no-flow test on TBU D-20 packerless completion. The test results are consistent with a passing test. SCANNED E° 1 5 2 ? Attachments: Photos (3) 2017-0415_No-FlowTBU_D-20_ae.docx Page 1 of 3 • • WAffiNfir 1114' 416- .. 1"--- MilP w , .., w m 3 0 ; . < , 0a ..., =I b o •air as as a) to of ,,, _ . ilii... r , .„ ,,,,_ _ „..,, , ,, .i. 7,.....: _ , . ,.:. os . , „... s. rn N .., ,. ,.. .... 411 . oI 0 a o E Z 0 -, o MII 11111111/11.. J. i row UMW0 dhillfr N o CO i5. acts, /� L ii O '3 =�� ,' 0 ++ C 7 CI U' U. . U m :14 e o - e m � Q =rr cWy d Q_Q ,_ ...ii ., ..,,,,,...:'4.;. '_...,% 'n O N o Z a • . 0 N Q pa H Q bA • k 0 O N Z of N AI M CA W H O I . ° _ I 1r\ • , f ' . , ., , ii ��- 1 \N �t.':# N. d" O y � � ' -_ t 1- , / , : , • . - ;Y4fP' . liVitt,,, 't 8V.1 .':. f , - f 1, j s t i t .may .i - { 2 • • VOF T A.1// 7 s., THE STATE Alaska Oil and Gas �� -sem '� Of Conservation Commission LAsKA ,,,,,,,,,_ __=_,_. ci iV= _= 333 West Seventh Avenue f GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 wa Main: 907.279.1433 O ' Fax: 907.276.7542 www.aogcc.alaska.gov Stan W. Golis 5 8493 LTJ 1 . Operations Manager Hilcorp Alaska, LLC 3800 Centerpoint Dr., Ste. 1400 Anchorage, AK 99503 Re: McArthur River Field, Middle Kenai G and Hemlock Oil Pools, TBU D-20 Permit to Drill Number: 169-095 Sundry Number: 317-033 Dear Mr. Golis: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown,a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, ' l----- -- -7 eaniel T. Seamount,Jr. Commissioner DATED this/ day of January,2017. RBDMS 1,k- 1- - 3 2017 • • RECEIVED STATE OF ALASKA JAN 2 3 2017 ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS A.OGCC 20 AAC 25.280 �r 1.Type of Request: Abandon 0 Plug Perforations 0 Fracture Stimulate 0 Repair Well ❑ Operations shutdown 0 I 1 Suspend ❑ Perforate 0• Other Stimulate ❑ Pull Tubing El Change Approved Program Plug for Redrill ❑ Perforate New Pool 0 Re-enter Susp Well ❑ Alter Casing 0 Other. Combo GUESP Completion P7 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number. Hilcorp Alaska,LLC Exploratory ❑ Development El A 169-095 3.Address: 3800 Centerpoint Drive,Suite 1400 Stratigraphic ❑ Service ❑ 6.API Number. Anchorage,AK 99503 50-733-20203-00 , 7.If perforating: 8.Well Name and Number. What Regulation or Conservation Order governs well spacing in this pool? CO 228A I Will planned perforations require a spacing exception? Yes 0 No 0 / Trading Bay Unit/D-20 ' 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL0018729 ' McArthur River Field/Middle Kenai G and Hemlock Oil Pools ' 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): 10,506 ' 10,028 . 10,045 . 9,593 2,542 psi WA 10,068&10,198 Casing Length Size MD ND Burst Collapse Structural Conductor 400' 33" 400' 399' Surface 3,006' 13-3/8" 3,006' 2,905' 3,090 psi 1,540 psi Production 9,674' 9-5/8" 9,674' 9,242' 5,750 psi 3,090 psi Tie-Back 9,467' 7-5/8" 9,467' 9,047' 6,890 psi 4,790 psi Liner 1,017' 7" 10,480' 10,003' 8,160 psi 7,020 psi Perforation Depth MD(ft): Perforation Depth ND(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 9,370-10,260 • 8,955-9,796 2-7/8"&3-1/2" 6.5#&9.2#/L-80 366',325'&9,305 Packers and SSSV Type: Packers and SSSV MD(ft)and ND(ft): Dual ESP Pkr,Model"D"Pkr(x2)&SSSV 341'(MD)341'(ND)10,068'(MD)9,615(TVD)10,198(MD)9,737(ND)&315(MD) 315(ND) 12.Attachments: Proposal Summary 0 Wellbore schematic Q 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch 0 Exploratory ❑ Stratigraphic❑ Development CI• Service ❑ 14.Estimated Date for 15.Well Status after proposed work: Commencing Operations: 3/1/2017 OIL 0 • WINJ ❑ WDSPL 0 Suspended ❑ 16.Verbal Approval: Date: GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Contact Dan Marlowe(907)283-1329 Email dmarlowe(rDhilcorp.com Printed Name Stan W.GolisD ' Title Operations Manager �j Signature ��` `�•s /L Phone (907)777-8356 Date i/I'3 / 2.& I I COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: ri^ 033 Plug Integrity 0 BOP Test Mechanical Integrity Test ❑ Location Clearance ❑ 115.f- ) 3 J � /-t,5 /� --�— Other: 114 3,56° �S., f�tJ f "f— Post Initial Injection MIT Req'd? Yes ❑ No ❑ LA--i-,..J r Spacing Exception Required? Yes ❑ No pi Subsequent Form Required: J Q--L/Q r'j RBI L `S --i-,..J - 3 Lii 17 AHERO Y // //7 Approved by: COMMISSIONER THE COMMISSION Date: 94 i M/{l- �prb ALtrt hr r.Ii 1 .t�%�„ Submit Form and Form 10-403 Revised 11/2015 a Ic tlid for 12 nths from the date of approval. Attachments in Duplicate • • Well Work Prognosis Well: D-20 Ha�.p Alaska,LLC Date: 01/23/17 Well Name: D-20 API Number: 50-733-20203-00 Current Status: Oil producer(ESP) Leg: Leg#: B-1 (SE) Estimated Start Date: March 01,2017 Rig: Moncla 404 Reg.Approval Req'd? 10-403 Date Reg.Approval Rec'vd: Regulatory Contact: Juanita Lovett 777-8332 Permit to Drill Number: 169-095 First Call Engineer: Dan Marlowe (907) 283-1329 (0) (907)398-9904 (M) Second Call Engineer: Stan Golis (907)777-8356(0) Current Bottom Hole Pressure: 3,438 psi @ 8,955'TVD 0.384 lbs/ft(7.38 ppg) Maximum Expected BHP: 3,438 psi @ 8,955'TVD 0.384 lbs/ft(7.38 ppg) Maximum Potential Surface Pressure: 2,542 psi Using 0.1 psi/ft gradient 20 AAC 25.280(b)(4) Brief Well Summary: The D-20 well is currently completed with a failing ESP(suspected holes in pump) installed March 2015.This work over will perforate the G-2 sands and replace the ESP with a combo Gas-Lift/ESP completion to restore productivity. r Last Casing Test: 02/28/2015 at 9,461'to 2,500 psig for 30 minutes on chart U l` Procedure: 1. MIRU Moncla Rig#404. 2. Circulate hydrocarbon off of well through the ESP.Work over fluid will be FIW. BOP's will be closed as needed to circulate the well. 3. ND Wellhead, NU BOP and test to 250psi low/3<500psi high. (Note: Notify AOGCC 48 hours in advance of test to allow them to witness test). 4. Monitor well to ensure it is static. 5. Unseat hanger and POOH with completion. 6. RU E-Line and perforate per program 7. PU and RIH with new combo gas-lift/ESP assembly. a. A high set packer, packer vent valve,and SSSV will be ran if well indicates ability to flow to surface. 8. If applicable-Set and test packer to 1,500 psig charting for 30 minutes. 9. Set BPV. NU tree,test same. 10. Turn well over to production 11. Schedule SVS testing with AOGCC as per regulations. 12. If applicable-Schedule no-flow with AOGCC as per regulations. Attachments: 1. Well Schematic Current 2. Well Schematic Proposed 3. Wellhead Schematic Current/Proposed (Same) 4. BOP Drawing 5. Fluid Flow Diagrams 6. RWO Sundry Revision Change Form • • Trading Bay Unit SCHEMATIC Well: D-20 Harare Alaska.lit Completed: 03/22/15 RKB to TBG Head=41.8' CASING DETAIL Tree connection:4-1/6"5,000# SIZE TYPE WT GRADE CONN ID TOP BTM. < \ 33" Conductor Surf 400' 1 m A 13-3/8" Surf Csg 61 K-55 Seal Lock 12.515 Surf 3006' Rr S 9-5/8" Prod Csg 40 N-80 Butt 8.835 Surf 4390' `g 3 9, 43.5 8.755 4390' 5204' 4,C=. ....:.... DV 5204' 5206' Collar 43.5 N-80 8.755 5206' 6156' g. S-95 Butt 6156' 7080' 9-5/8" Prod Csg 47 8.681 7080' 9072' AR-95 Seal Lock 9072' 9674' 7-5/8" Tie-Back 29.7 L-80 SLIJ-II 6.875 Surf 9,467' .c. 7" Liner 29 N-80 X-Line 6.185 9463' 10,480' if TUBING DETAIL 3-1/2" 9.2# L-80 Supermax 2.992 Surf 325' 4 2-7/8" _ 6.5# L-80 8rd EUE 2.441 325' 366' 5 3-1/2" 9.2# L-80 Supermax 2.992 366' 9,309' El 67 JEWELRY DETAIL 8 • NO. Depth ID Item ° 0 CIW 4-1/2"EUE 8rd X Butt Tbg.Hanger. o G-2 1 315' SSSV 2 341' 2.441 7-5/8"Dual ESP Packer w/Vent valve G-4 3 356' 2.313 X Nipple w/collar 4 9,309' - Discharge,Bolt-On ,: G-5 5 9,310' - Pump(x2)513 Series,093 Stage G ,Csg Shoe 6 _ _ 9,352' - Intake 9660'DIL 7 9,371' - Motor 562,340 H/3360V/61A 1 i 1 a 8 9,407' - Anode Centrilizer °°° = = 9 10,068' 3.25 Baker Model"D"Pkr. mi0, '' 10,078' 2.75 Otis"X"Nipple,size 2.75 10,086' 3.00 Bell Guide HK-1 10 10,198' 3.25 Baker Model"D"Pkr. 10,206' 2.625 Otis"Q"Nipple,size 2.625 10,212' Mule Shoe _=-IK-3 Brief Details&Info:To date _ Spudded D-20 on 9/20/69.TD @ 10,506'on 10/25/69.Completed&RR on 11/06/69. •Hole Section MWT: •Approximate Rotating hrs: `,..Fal ragged al o 17-1/2"to 3050' 9.9 to 10 ppg o 33" 60 hrs p,,.,on 03n8n5 @ 10,049 K-q K.r:... = o 12-1/4"to 9,748' 9.8 to 10 ppg o 13-3/8" 285 hrs 0 8-1/2"to 10,506 0 9-5/8" Sl hrs ,,4 �' ''''', .< 0 7" 16hrs SIF: - .e PERFORATION DETAIL =N - Zone Top Btm(MD) Top Btm Amt. SPF Last Perf Date Present Condition ■I (MD) (TVD) (TVD) g 8 ,' = G-2 9,370' 9,388' 8,955' 8,972' 18' 5 03/19/15 Open NI' = G-4 9,478' 9,484' 9,057' 9,063' 6' 5 03/19/15 Open Fill tagged on 8126/86@ 10,201' _HK-5 G-5 9,610' 9,627' 9,182' 9,198' 17 5 03/19/15 Open Sqz 9,680' 9,681' 9,248' 9,249' 1' 4 11/2/1969 Sqz 100 sx cmt. N°Joy°n,,ns,.tb• 10.: ::JI Sqz 9,750' 9,751' 9,315' 9,315' 1' 4 10/30/1969 Sqz 75 sx cmt. thru pkr.during •:•:•:•:•, 10 HK-1 9,820' 9,885' 9,381' 9,442' 65' 20 6/15/1992 Open f/Production WO In 71183 t HK-1 9,828' 9,862' 9,388' 9,420' 34' 5 03/19/15 Open - s f HK-3 9,905' 9,950' 9,461' 9,503' 45' 16 6/15/1992 Open f/Production is-------'-‘ HK-4 9,908' 9,932' 9,464' 9,486' 24' 5 03/19/15 Open HK-4 9,950' 10,065' 9,503' 9,611' 115' 16 6/15/1992 Open f/Production HK-4 9,964' 9,986' 9,516' 9,537' 22' 5 03/19/15 Open K 6 HK-5 10,070' 10,190' 9,616' 9,730' 120' 16 Jul-75 Open f/Production HK-6 10,230' 10,260' 9,767' 9,796' 30' 4 Jul-75 Open f/Production 4/29/75 D-27 collided w/D-20 while drilling 17-1/2"surface hole.Communication to Inlet.Spotted 500sx of G cmt @ 400' in D-27.Possible length of breach in 13-3/8"is 1488'to 1497'.Penetration in D-20 9-5/8"@ 1497'. PBTD=10,430' TD=10,506' MAX HOLE ANGLE=21°,41 2100' 7/75 WO sqz'd 9-5/8"csg @ 1497'4x.Total cmt placed 650 sx. Updated: 04/21/15 by_ILL 0 • Trading Bay Unit PROPOSED Well: D-20 Hileorp Alaska.LU Completed: Future RKB to TBG Head=41.8' CASING DETAIL Tree connection:4-1/6"5,000# SIZE TYPE WT GRADE CONN ID TOP BTM. , di i I I. , 33" Conductor Surf 400' 1 , 13-3/8" Surf Csg 61 K-55 Seal Lock 12.515 Surf 3006' \'''4;}, i 9-5/8" Prod Csg 40 N-80 Butt 8.835 Surf 4390' 43.5 8.755 4390' 5204' DV 5204' 5206' Collar 43.5 N-80 Butt 8.755 5206' 6156' '•.;1 9-5/8" Prod Csg S-95 6156' 7080' 47 8.681 7080' 9072' AR-95 Seal Lock 9072' 9674' 7-5/8" Tie-Back 29.7 L-80 SLIJ-II 6.875 Surf 9,467' r e ?. 7" Liner 29 N-80 X-Line 6.185 9463' 10,480' m 3-11 7-i9 sr _ TUBING DETAIL Ile 3-1/2" 9.2# Supermax 2.992 Surf ±9,200' s x JEWELRY DETAIL NO. Depth Depth ID Item 12 (MD) (ND) g }J Tubing Hanger 1 ±350' ±350' Contingent-SSSV :IR r .. G-2 P4 2 ±380' ±380' Contingent-Packer w/Vent valve t3 3 ±2,306' ±2,250' GLM#1 • G-4 4 ±4,165' ±4,000' GLM#2 5 ±5,526' ±5,300' GLM#3 G-5 6 ±6,420' ±6,150' GLM#4 ,Csg Shoe 7 ±7,048' ±6,750' GLM#5 @9660'DIL 8 ±7,582' ±7,250' GLM#6 PH8 = 9 ±8,108' ±7,750' GLM#7 0 0 = = 10 ±8,628' ±8,250' GLM#8 Mt! '` 11 ±9,154' ±8,750' GLM#9-Orifice 12 ±9,184' ±8,779' Contingent-X Nipple HK-1 13 ±9,285' ±8,875' - Bottom of ESP 14 10,068' 9,615' 3.25 Baker Model"D"Pkr. 10,078' 9,624' 2.75 Otis"X"Nipple,size 2.75 -IK-3 10,086' 9,632' 3.00 Bell Guide = 15 10,198' 9,737' 3.25 Baker Model"D"Pkr. 10,206' 9,745' 2.62 Otis"Q"Nipple,size 2.625 Fill fagged on 03/18/15 @ 10,045' IK-4 5 r* Gam:: - 10,212' 9,750' Mule Shoe , I, ly ' ' , , - 14 PERFORATION DETAIL e f _ Zone Top(MD) Btm(MD) (rvp) Btm(TVD) Amt. SPF Last Perf Date Present Condition 31 std = G-2 9,370' 9,388' 8,955' 8,972' 18' 5 03/19/15 Open 2 o A, = J G-7 +9,421' +9,445' +9,004' ±9,026' ±24' Future 81 }ww - G-4 9,478' 9,484' 9,057' 9,063' 6' 5 03/19/15 Open l Fill fagged on ' ''11#. 8/28/88@10,201' HK-5 G-5 9,610' 9,627' 9,182' 9,198' 17 5 03/19/15 Open k'' Sqz 9,680' 9,681' 9,248' 9,249' 1' 4 11/2/1969 Sqz 100 sx cmt. : IN No Joy on 2-1116"tb• A Sqz 9,750' 9,751' 9,315' 9,315' 1' 4 10/30/1969 Sqz 75 sx cmt. thin pkr doting -.15 HK-1 9,820' 9,885' 9,381' 9,442' 65' 20 6/15/1992 Open f/Production wo to 11183 -� HK-1 9,828' 9,862' 9,388' 9,420' 34' 5 03/19/15 Open R HK-3 9,905' 9,950' 9,461' 9,503' 45' 16 6/15/1992 Open f/Production • ■M. HK-4 9,908' 9,932' 9,464' 9,486' 24' 5 03/19/15 Open HK-4 9,950' 10,065' 9,503' 9,611' 115' 16 6/15/1992 Open f/Production HK-4 9,964' 9,986' 9,516' 9,537' 22' 5 03/19/15 Open k. ? . HK-5 10,070' 10,190' 9,616' 9,730' 120' 16 Jul-75 Open f/Production :,. =HK-6 HK-6 10,230' 10,260' 9,767' 9,796' 30' 4 Jul-75 Open f/Production cr ..,, y• :A 4/29/75 D-27 collided w/D-20 while drilling 17-1/2"surface hole.Communication to Inlet.Spotted 500sx of G cmt @ 400' PBTD=10,430' TD=10,506' in D-27.Possible length of breach in 13-3/8"is 1488'to 1497'.Penetration in D-20 9-5/8"@ 1497'. MAX HOLE ANGLE=21°,t 2100' 7/75 WO sqz'd 9-5/8"csg @ 1497'4x.Total cmt placed 650 sx. Updated: 01/23/17 by JLL • D• Varden Platform D-20 Current 12/19/2014 ilsl.nrp ila:ka.LT:f, Dolly Varden Tubing hanger,FMC-TC-ESP, D-20 11 X 3>5 NS-CT lift and susp, 13 3/8 X 9 5/8 X 7 5/8 X 300-4 seal pocket,w/3" 2 7/8 Type H BPV profile,2-3/8 CCL,Alloy material BHTA,Bowen,3 1/8 5M FE X 3" Bowen Quick Union u, ni Valve,swab,WKM-M, "' '•' 3 1/8 5M FE,HWO, , T-24 O ' IMO Valve,WKM-M,3 1/8 5M FE,w/ 15"OMNI operator Valve,wing,WKM-M, 2 1/16 SM FE,HWO, 0(0)4 OQ I T-24 • . oeilMer m PIC" tle Valve,lower master,WKM-M, 'ti 3 1/8 5M FE,HWO,T-24 ' O .10 Adapter,FMC-A-5-EC,11 5M rotating flange x 3 1/8 5M rotating top,300-4 pocket prep,2-CCL ports,3.266 centers 1 Multibowl wellhead assy, �_Ij � �{■_� �i ._■_ Cactus MBS-2 13 5/8 3M x 11 5M,w/4- Valve,WKM M,2 1/16 SM FE, - 2 1/16 5M SSO,prepped for HWO,DD 7 5/8 mandrel hanger,and .■ �I t` tubing hanger,9 5/8 HPS ��_�' _—I1 °:!I �\ J ' �-�` bottom —►1'— __rPPM T: d III I'L 'I 1.1 jet Valve,WKM-M,2 1/16 5M FE, • HWO,DD JL 111u.'-''' _ o II►' Casing head,CIW-WF, i r 13 5/8 3M X 13 3/8 casing illi .� Ili Valve,CIW F,2 1/16 3M FE, thread bottom,w/2-2 1/16 = , A _ HWO,AA trim 5M EFO 111111 11 11141i° ` /111°A- E IIS • • Do 11y Varden Platform Moncla BOP 12/19/2016 Uilenrp Alaska-113. Ill 111 Iii111ili INIMMENIMENEM 4 54' P 4 Cu tutu 5 -gag clW-u 5mo Variable rams 2 7/8-5 4.67' BMA _ IMO Blind Rams 13 5/8-5000 —_ 7718 Choke and Kill valves 2 1/16 5M I o i_ 1 vit) 0- p I 2.26' � �s� A DI Mud Cross (• r =' (i x E 41/185MEFO � x1 ��jJ��7_ ) •$11 1111 1111 111 1111 Riser 135/85M FE X 135/8 SM FE 1111 ilii iii iii III III III 1111 1111 iuI Spacer spool 135/85M FE X115M iii iii lii iii iii o 0 O O u O U •O O U,O O•u O u 0 u u 0 u U O • o _ o _ ti o Ln .-+ N m d V, tO n co rn 2 f 2 2 2 2 2 2 2 2 u a a a a a C 000fl Li 00000 - 0 UUUVO .e N en v en w N N m Cr in 00 n w co, .-1 -o v o 0 'O D U U U -O -O U v v 0 0 0 0 0 L 0 0 0 0 0 0 0 0 '66566 N v f 4 3 U! 366666666 '6 '68 (2 > . - - 2 - 0. C C '' 21 N N N N Ul j 4- >▪ EEEEE J w o 0 0 0 0 U1 0 0 0 0 0 o a g ,;.? > d a 6 d 6 0 :E U 0000000000 V1 � Ln 01 CL v y w o a w o ' 0c m m v m m O to 2, OE 2 z 14 H N Cr) V w ft 11, Q 0 aO N) - -cs- . ZO (n0 �U c o cc h //�' o / �> J c7 H Clh, In 1111...... ' -.4 (LIG: ialTD ilii �- a v m 0 < co , w a a • 0 z U) z O O Z ow aDz CO � Q 2 J fn J rt] D CL 0 Z cpLtO0Q QQ (n � zrY• W U < Oov U JWO O 0 � � w r 1- JO Z w r) . co ao N Q ° F-- -I 0 0 U U- 0 G • O_ O U O u O 00 ,-, 0 O U O u O u u O u U 0 • o o _ ,1 m a N •' N N N N l0 h a0 01 5 W 2 2 2 2 2 2 2 2 2 u 22222 f. OUUUUUUUU o .-1 N m N N v .-1 N m Cr N 0 N 00 01 Cl -o a U To v o 00 -0000 -00 -0 v O O O _O O U N 0 0 0 0 0 0 0 0 0 O - 00000W a L C C C C C G C G C Y L 2 a, 6. O. 6 6 00 > 0 d 3 3 3 Y 3 Y Y Y 0) o > EEEEE -' rco o o o o o o o o o o a L „+ 0 3 3 J J - L L L L L L L tA = U L L> a 1 d 0. 1 Y Y I U U U U U U U U U U.U 0I 2 N 0 a o Y W O5 O ll o C N N U 00 O qft II II co to _ (O I U w Z z d W'Y I I�Y a0 tom) 'tZO DI QIw 0 C / aO LL ° w 12 H p ;_r c 1 . _ III III d U v O < m F w a 1-U H IT_ 0 Z Q I- CO Q -J O Z p Z v Q pd I dU) z J Z ❑ _ 2a A 2 � Q oQOct U � O—�, awZ0 QOO OO i J J J D J O p 2 • JOO 1--- in x a� LL. ZO "m z Q 0 ~ Za J Q Na p. D 0 CtU • S Moncla Rig 404 BOP Test Procedure Attachment#1 Hilcorp Alaska,LLC Attachment #1 Hilcorp Alaska, LLC - BOP Test Procedure: Moncla Rig 404, WO Program — Oil Producers, Water Injectors Pre Rig Move 1) Blow down well, bleed gas to Well Clean Tank that is vented thru flare to atmosphere 2) Load well with FIW to kill well. • Note: Fluid level will fall to a depth that balances with reservoir pressure. 3) Shoot fluid level at least 24 hours before moving on well. 4) Shoot fluid level again,right before ND/NU. Confirm that well is static. Initial Test(i.e.Tubing Hanger is in the Wellhead) If BPV profile is good 1) Set BPV. ND Tree. NU BOP. 2) MU landing joint. Pull BPV. Set 2-way check in hanger. 3) Space out test joint so end of tubing(EOT)is just above the blind rams. 4) Set slips, mark same. Test BOPE per standard test procedure. If the tubing hanger won't pressure test due to either a penetrator leak or the BPV profile is eroded and/or corroded and BPV cannot be set with tree on.Profile and/or landing threads must be prepped while tree is off.Worst Case: BPV profile and landing threads are bad. 1) Attempt to set BPV through tree. If unsuccessful,shoot fluid level. 2) If fluid level is static from previous fluid level shots, notify Hilcorp Anchorage office that the well is static and the tree must be removed with no BPV.As approved in the sundry,proceed as follows: a) ND tree with no BPV b) Inspect and prepare BPV profile to accept a 2-way valve,or prepare lift-threads to accept landing joint to hold pressure. If well is a producer and the culprit is scale,attempt to clean profile with Muriatic acid and a wire brush or wheel. c) Set 2-way check valve by hand,or MU landing(test)joint to lift-threads d) For ESP wells-Ensure that cap is on cable penetrator e) NU BOP. Test BOPE per standard procedure. 3) If both set of threads appear to be bad and unable to hold a pressure test and/or a penetrator leaks, notify Operations Engineer(Hilcorp), Mr.Guy Schwartz(AOGCC)and Mr.Jim Regg(AOGCC)via email explaining the wellhead situation prior to performing the rolling test. AOGCC may elect to send an inspector to witness. As outlined and approved in the sundry, proceed as follows: a) Nipple Up BOPE b) With stack out of the test path,test choke manifold per standard procedure c) Conduct a rolling test: Test the rams and annular with the pump continuing to pump,(monitor the surface equipment for leaks to ensure that the fluid is going down-hole and not leaking anywhere at surface.) d) Hold a constant pressure on the equipment and monitor the fluid/pump rate into the well. Record the pumping rate and pressure. e) Once the BOP ram and annular tests are completed,test the remainder of the system following the normal test procedure(floor valves,gas detection,etc.) + • • • Moncla Rig 404 BOP Test Procedure Hilcoep Alaska, LLC #1 f) Record and report this test with notes in the remarks column that the tubing hanger/BPV profile/ penetrator wouldn't hold pressure and rolling test was performed on BOP Equipment and list items, pressures and rates. 4) Pull hanger to surface. (Requires tubing cuts as necessary to free tubing). CBU to displace annulus and tubing with kill weight fluid. 5) If a rolling test was conducted,remove the old hanger, MU new hanger or test plug to the completion tubing. Re-land hanger(or test plug)in tubing head. Test BOPE per standard procedure. Subsequent Tests(i.e.Test Plug can be set in the Tubing-head) 1) Remove wear bushing. a) Use inverted test plug to pull wear busing. MU to joint of tubing. b) Thread into wear bushing c) Back out hold down pins d) Pull and retrieve wear bushing. 2) Break off test plug and invert same-RIH with test plug on joint of tubing. Install a pump-in sub w/test line plus an open TIW or lower Kelly valve in top of test joint w/open IBOP. 3) Test BOPE per standard procedure. STANDARD BOPE TEST PROCEDURE(after 2-way check or test plug is set) 1) Fill stack and all lines with rig pump-install chart recorder on test line connected to pump-in sub below safety valve and IBOP in test joint assembly. 2) Note: When testing, pressure up with pump to desired pressure,close valve on pump manifold to trap pressure and read same with chart recorder(test pressures will be indicated in Sundry). 3) Referencing the attached schematics test rams and valves as follows. a) Close ft valve on standpipe manifold,close valves 1,2, 10 on choke manifold and close the annular preventer,open safety valve on top of test jt and close IBOP. Pressure test to 250 psi for 5 minutes and 2,500 psi high for 5 minutes. If passes after 5 minutes on each,bleed off pressure back to tank and open annular. b) Close pipe rams and open annular preventer,close safety valve and open IBOP on test joint,close outside valve on kill side of mud cross,open 15t valve of standpipe,close valves 3,4&9 on choke manifold,open valves 1&2 on choke manifold. Test to 250 psi for 5 minutes and 3,000 psi high for 5 minutes. If passes after 5 minutes on each,bleed off pressure back to tank. c) Test Dual Rams. If the well has dual tubing,and dual rams are installed in the stack,test the dual rams by picking up two test joints with dual elevators and lowering them into stack and position them properly in the dual rams. Close rams. Test to 250 psi for 5 minutes and 3,000 psi for 5 minutes. If passes after 5 minutes on each,bleed off pressure back to tank. d) Close inside valve/open outside valve on kill side of mud cross,close valves 5&6/open valves 3&4 on choke manifold. Test to 250 psi for 5 minutes and 3,000 psi for 5 minutes. If passes after 5 minutes on each,bleed off pressure back to tank. e) Close manual and super choke/open valves 5&6 on choke manifold. Pressure up to"'1200 psi and bleed off 200—300#s recording change and stabilization. If passes after 5 minutes, bleed of pressure back to tank. f) Close HCR(outside valve on choke side of mud cross),open manual&super choke. Test to 250 psi for 5 minutes and 3000 psi for 5 minutes. If passes after 5 minutes on each, bleed off pressure back to tank. s • Moncla Rig 404 BOP Test Procedure Hilcorp Alaska.LLC Attachment#1 g) Close inside valve/open outside valve(HCR)on choke side of mud cross. Test to 250 psi for 5 minutes and 3000 psi for 5 minutes. If passes after 5 minutes on each,bleed off pressure back to tank. h) Ensure all pressure is bled off-open pipe rams and pull test joint leaving test plug/2-way check in place. Close blind rams and attach test line to valve 10 on choke manifold,close valve 7&8/open valve 10 on choke manifold. Test to 250 psi for 5 minutes and 3000 psi for 5 minutes. If passes after 5 minutes on each, bleed off pressure back to tank. i) Test additional floor valves(TIW or Lower Kelly Valve)and IBOPs as necessary. STANDARD TEST PROCEDURE OF CLOSING UNIT(ACCUMULATOR) 1) This is a test of stored energy. Shut off all power to electric and pneumatic pumps. 2) Record "Accumulator Pressure". It should be+/-3,000 psi. 3) Close Annular Preventer,the Pipe Rams,and HCR. Close 2nd set of pipe rams if installed(e.g. dual pipe rams). Open the lower pipe rams to simulate the closing volume on the blinds. 4) Allow pressures to stabilize. 5) While stabilizing: Record pressure values of each Nitrogen bottle and average over the number of bottles. (i.e. Report might read"10 bottles at 2,150 psi"). 6) After accumulator has stabilized, record accumulator pressure again. This represents the pressure and volume remaining after all preventers are closed. (The stabilized pressure must be at least 200 psi above the pre- charge pressure of 1,000 psi). 7) Turn on the pump and record the amount of time it takes to build an additional 200 psi on the accumulator gauge. This is usually+/-30 seconds. 8) Once 200 psi pressure build is reached,turn on the pneumatic pumps and record the time it takes for the pumps to automatically shut-off after the pressure to builds back to original pressure(+/-3,000 psi). Note: Make sure the electric pump is turned to"Auto", not"Manual"so the pumps will kick-off automatically. 9) Open all rams and annular and close HCR to place BOPE back into operating position for well work. 10) Fill out AOGCC report. FINAL STEP,FINAL CHECK 1) Test Gas Alarms 2) Double check all rams and valves,for correct operating position 3) Fill out the AOGCC BOPE Test Form(10-424)in Excel Format and e-mail to AOGCC and Juanita Lovett. Document both the rolling test and the follow up tests. • 0 � Ea / > W2 Q73' ° o 6 § 2 E 0 o co / 2 kcL E= f E cm 0C 7 e m 5 o § � E f a= » a a< ±.- k / 2 U) m 7 � I El c \/ 0. •.=. g7 % \ co -0 ) a)OW 2 � 2 o u $ % CD>- E/ 2 J @ a) 0 9 2 / o CD _ & U 2 m 0_ o a > 14. o 09 0 o. (11 > &C iti =0 -ocUf 0 \ L. 4. a) k 13) (2 E G © 2 O 2 f •a a a 16 \ CO ±11 co C CA § \ f . 2 Qp 2 LU ■ _ 0 V.J%± ■ 0 1-4 0 0. �� as a)Q 4 ' « // 0 :a. / oCL x % & § 0. Q $ 2 » a) I q 0 a C � � C.) *0 co0 .o 4) 0 2 ■ 3 x t £ 2 it ✓ .. o % a k a L. E0 > k 0 0 o_ 2 C CO a) < 0_ y •F 77-4. • 0 4§,P',�\�//7. s& THE STATE Alaska Oil and Gas tv 0"'�^dam Of TT cKA Conservation Commission = _ A1.1V it-PT i� 333 West Seventh Avenue ±2 ' GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279.1433 OF ALAS I- Fax: 907.276.7542 www.aogcc.alaska.gov Stan Golis Operation Manager1 Hilcorp Alaska, LLC SCAtit4ED BAR 2 9 P 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: McArthur River Field, Middle Kenai G and Hemlock Oil Pools, TBU D-20 Permit to Drill Number: 169-095 Sundry Number: 316-642 Dear Mr. York: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown,a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, /0 „,,,,,zy, Cathy P Foerster y�� Chair DATED this`t'"day of January, 2017. RBDMS L JAN 2 6 2017 RECEIVED STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION DEC 2 O 15 APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 AO 1.Type of Request: Abandon ❑ Plug Perforations❑ Fracture Stimulate 0 Repair Well 0 Operations shutdown 0 Suspend ❑ Perforate 0 Other Stimulate ❑ Pull Tubing 0, Change Approved Program 0 Plug for Redrill 0 Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other. Combo GUESP Completion P1• 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number. Hilcorp Alaska,LLC ., Exploratory 0 Development j ' 169-095 t 3.Address: 3800 Centerpoint Drive,Suite 1400 Straligraphic 0 Service ❑ 6.API Number. Anchorage,AK 99503 50-733-20203-00 t 7.If perforating: 8.Well Name and Number. What Regulation or Conservation Order governs well spacing in this pool? N/A al Will planned perforations require a spacing exception? Yes ❑ No CI Trading Bay Unit/D-20 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL0018729 - McArthur River Field/Middle Kenai G and Hemlock Oil Pools 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP(psi): Plugs(MD): Junk(MD): 10,506 , 10,028 , 10,045 s , 9,593 2,542 psi WA 10,068&10,198 Casing Length Size MD TVD Burst Collapse Structural Conductor 400' 33" 400' 399' Surface 3,006' 13-3/8" 3,006' 2,905' 3,090 psi 1,640 psi Production 9,674' 9-5/8" 9,674' 9,242' 5,750 psi 3,090 psi Liner 9,467' 7-5/8" 9,467' 9,047' 6,890 psi 4,790 psi Liner 1,017' 7" 10,480' 10,003' 8,160 psi 7,020 psi Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 9,370-10,260 4 8,955-9,796 2-7/8"&3-1/2" 6.5#&9.2#/L-80 366',325'&9,309' Packers and SSSV Type: Packers and SSSV MD(ft)and ND(ft): Dual ESP Pkr,Model"D"Pkr(x2)&SSSV 341'(MD)341'(TVD)10,068'(MD)9,615(TVD)10,198(MD)9,737(TVD)&315(MD) 315(TVD) 12.Attachments: Proposal Summary Q Wellbore schematic I] 13.Well Class after proposed work: Detailed Operations Program 0 BOP Sketch 0 Exploratory 0 Stratigraphic❑ Development ID' Service 0 14.Estimated Date for 15.Well Status after proposed work: Commencing Operations: 2/1/2017 OIL p 4 WINJ ❑ WDSPL 0 Suspended 0 16.Verbal Approval: Date: GAS ❑ WAG ❑ GSTOR 0 SPLUG 0 Commission Representative: GINJ 0 Op Shutdown ❑ Abandoned ❑ 17.I hereby certify that the foregoing Is true and the procedure approved herein will not be deviated from without prior written approval. Contact Dan Marlowe(907)283-1329 Email dmariowertthilcorp.com Printed NameStan W.Golfs Title Operations Manager Signature �J`cam.. Phone (907)777-8356 Date 17- ( Z_2 / -D t Co COMMISSION USE ONLY Conditions of approval: Notify Comm ssion so that a representative may witness Sundry Number. ''/ Plug Integrity 0 BOP Test LTJ Mechanical Integrity Test ❑ Location Clearance 0 Other: 4 3 cop /'>.; Zs'ea,K) .---r-4,„ f-- Post Initial Injection MIT Req'd? Yes ❑ No 0 Spacing Exception Required? Yes n No Subsequent Form Required: / D-- I-, 1' RBDMS (,L- JAN L 6 2017 l L APPROVED BY Approved by: t COMMISSIONER THE COMMISSION Date: /— (/T –/�/ `I /'?_ Submit Form and Form 10-403 Revised 11/2015 Approved application Is vatiOR1it1AL Ricirm pproval Attaach in Duplicate A(3/-4�(4 • 14 Well Work Prognosis Well: D-20 unrorP niatrA,1.I.0 Date: 12/19/16 Well Name: D-20 API Number: 50-733-20203-00 Current Status: Oil producer(ESP) Leg: Leg#: B-1 (SE) Estimated Start Date: February 01,2017 Rig: Moncla 404 Reg.Approval Req'd? 10-403 Date Reg.Approval Rec'vd: Regulatory Contact: Juanita Lovett 777-8332 Permit to Drill Number: 169-095 First Call Engineer: Dan Marlowe (907)283-1329(0) (907)398-9904 (M) Second Call Engineer: Stan Golis (907)777-8356(0) Current Bottom Hole Pressure: 3,438 psi @ 8,955'TVD 0.384 lbs/ft(7.38 ppg) Maximum Expected BHP: 3,438 psi @ 8,955'TVD 0.384 lbs/ft(7.38 ppg) Maximum Potential Surface Pressure: 2,542 psi Using 0.1 psi/ft gradient 20 AAC 25.280(b)(4) Brief Well Summary: The D-20 well is currently completed with a failing ESP(suspected holes in pump)installed March 2015.This work over will replace the ESP with a combo Gas-Lift/ESP completion to restore productivity. Last Casing Test: 02/28/2015 at 9,461'to 2,500 psig for 30 minutes on chart / e5')- j. Procedure: 1. MIRU Moncla Rig#404. 2. Circulate hydrocarbon off of well through the ESP.Work over fluid will be FIW. BOP's will be closed as needed to circulate the well. 3. ND Wellhead,NU BOP and test to 250psi low/3,500psi high.(Note: Notify AOGCC 48 hours in advance of test to allow them to witness test). 4. Monitor well to ensure it is static. 5. Unseat hanger and POOH with completion. 6. PU and RIH with new combo gas-lift/ESP assembly. a. A high set packer, packer vent valve,and SSSV will be ran if well indicates ability to flow to surface. 4/ 7. If applicable-Set and testpacker tl 5n0 psig charting for 30 minutes. 8. Set BPV. NU tree,test same. 9. Turn well over to production 10. Schedule SVS testing with AOGCC as per regulations. 11. If applicable-Schedule no-flow with AOGCC as per regulations. Attachments: 1. Well Schematic Current 2. Well Schematic Proposed 3. Wellhead Schematic Current/Proposed(Same) 4. BOP Drawing 5. Fluid Flow Diagrams 6. RWO Sundry Revision Change Form • • Trading Bay Unit SCHEMATIC Well: D-20 llit'orr,Ah„kn,,,u: Completed: 03/22/15 RKB to TOG Head=41.8' CASING DETAIL Tree connoction:4-1/6"5,00011 SIZE TYPE WT GRADE CONN ID TOP BTM. �+ ,) t)/1, 11iiii 33" Conductor Surf 400' 113-3/8" Surf Csg 61 K-55 Seal Lock 12.515 Surf 3006' \��'•, _ 2 1) 9-5/8" Prod Csg 40 N-80 Butt 8.835 Surf 4390' ` , 3 'I ' 435 8.755 4390' 5204' V 1 i i ) Dollar 5204' 5206' >? III 43,5 N-80Dutt 8.755 5206' 6156' 5-95 6156' 7080' 9-5/8" Prod Csg ill St .�� 47 8.681 7080' 9072' AR-95 Seal lock 9072' 9674' Ti) 7-5/8" Liner 29.7 L-80 SLI1-II 6.875 Surf 9,467' ## _7" Liner 29 N-80 X-Line 6.185 9463' 10,480' TUBING DETAIL 3-1/2" 9.211 L-80 Supermax 2.992 Surf 325' 4 2-7/8" 6,51$ L-80 8rd EUE 2.441 325' 366' I0 5 "`°`y,a. 31/2" 9.21$ L-80 Supermax 2.992 366' 9,309' 6 7 JEWELRY DETAIL 8 ;`� NO. Depth ID Item A !;: 'r 0 CIW 4-1/2"EUE 8rd X Butt Tbg.Hanger. t -i G-2 1 315' SSSV :`,:20 IS' 2 341' 2.441 7-5/8"Dual ESP Packer went valve G.4 3 356' 2.313 X Nipple w/collar 1.' k 4 9,309' - Discharge,Bolt-On ,J G-5 5 9,310' - Punip(x2)513 Series,093 Stage '4. ,Qsg Shoe 6 9,352' - Intake , Q 9660'D L 7 9,371' - Motor 562,340 H/3360V/61A L306 f= 8 9,407' - AnodeCentrilizer 8--- -- _ 9 10,068' 3.25 Baker Model"D"Pkr. 1a ,7- 10,078' 2.75 Otis"X"Nipple,size 2.75 10,086' 3.00 Bell Guide HK-1 10 10,198' 3.25 Baker Model"D"Pkr. .-.• 10,206' 2.625 Otis"Cr Nipple,size 2.625 10,212' Mule Shoe _ '-•KIK-3 Brief Details&Info:To date Spudded D-20 on 9/20/69.TO @ 10,506'on 10/25/69.Conikpleted&RR on 11/06/69. •Hole Section MWT: o 17-1/2"to 3050' 9,9 to 10 ppg *Approximate Rotating hrs: !j °i°" �60o 33" 60 hrs K, on OA16n6010,06S�.,K-4 0 12-1/4"to 9,748' 9.8 to 10 ppg o 13-3/8" 285 hrs ''' 0 8.1/2•'to 10,506 o 9-5/8" 51 hrs :: '')' o 7" 16 hrs fit �...`',,1 :::e . '' 9 PERFORATION DETAIL . ' Top Top Btn1 8 s ;1 �.I. Zone Btm(MD) Amt. SPF Last Perf Date Present Condition (MD) (ND) (ND) ri, g G-2 9,370' 9,388' 8,955' 8,972' 18' 5 03/19/15 Open ,,,. ,J1 = G-4 9,478' 9,484' 9,057' 9,063' 6' 5 03/19/15 Open 1 t FJ Logged on r 6/26173010,201' HK-5 G-5 9,610' 9,627' 9,182' 9,198' 17 5 03/19/15 Open Sqz 9,680' 9,681' 9,248' 9,249' 1' 4 11/2/1969 Sqz 100 sx cmt. he,uyun 1.„16,r° SI.:::::::: 1 !.i Sqz 9,750' 9,751' 9,315' 9,315' 1' 4 10/30/1969 Sqz 75 sx cmt. `kig, d"tlnq ' 1 10 HK-1 9,820' 9,885' 9,381' 9,442' 65' 20 6/15/1992 Open f/Production 1Y0 in lilt] '' �, HK-1 9,828' 9,862' 9,388' 9,420' 34' 5 03/19/15 Open {N =MI 11K-3 9,905' 9,950' 9,461' 9,503' 45' 16 6/15/1992 Open f/Production st �' HK-4 9,908' 9,932' 9,464' 9,486' 24' 5 03/19/15 Open x1 ,--.-- ..,...;,-. ' HK-4 9,950' 10,065' 9,503' 9,611' 115' 16 6/15/1992 Open f/Production HK-4 9,964' 9,986' 9,516' 9,537' 22' S 03/19/15 Open 1��= ::rEiHK-6 HK-5 10,070' 10,190' 9,616' 9,730' 120' 16 Jul-75 Open f/Production CX 11K-6 10,230' 10,260' 9,767' 9,796' 30' 4 Jul-75 Open f/Production $r r , . 4/29/75 U-27 collided w/I)-20 while drilling 17-1/2"surface hole.Communication to Inlet.Spotted 500sx ofG cmt @ 400' P010"10,430' TD=10,606' in 1)-27.Possible length of breach in 13-3/8"is 1488'to 1497'.Penetration in 1)-20 9-5/8"(i0 1497'. MAX HOLE ANGLE=21°,@ 2100' 7/75 WO sgr.'d 9-5/8"esg(�1497'4x.'Total cm(placed 650 sx. Updated: 04/21/15 by ILL • S Trading Bay Unit . IliPROPOSED Well: D-20 HBcuzgAtnskn,l.1.0 Completed: Future RKt3 to TUG Head=41.8' CASING DETAIL Tree connection:4-116"5,000# SIZE TYPE WT GRADE CONN ID TOP BTM. - ¢ 33" Conductor Surf 400' N 1 13-3/8" Surf Csg 61 K-55 Seal Lock 12.515 Surf 3006'* 2 '' 9-5/8" Prod Csg 40 N-80 Butt 8.835 Surf 4390' 43.5 8.755 4390' 5204' CollarD 5204' 5206' ; 41 � 43.5 N-80 Butt 8.755 5206' 6156' Lx 9-5/8" Prod Csg 5-95 6156' 7080' 47 8.681 7080' 9072' .f AR-95 Seal Lock 9072' 9674' :�j ;; 7-5/8" Liner 29.7 L-80 SLIT-II 6.875 Surf 9,467' 7" Liner 1111 29 N-80 X-line 6.185 9463' 10,480' ,# Ill 3.1 TUBING DETAIL 3-1/2" 9.211 L-80 Supermax 2.992 Surf ±9,260' 11 JEWELRY DETAIL i.' ( NO. Depth Depth ID Item 4 .' (MD) (TVD) J i j 6.2 Tubing Hanger NI "; - 12 r #350' ±350' Contingent-SSSV (+ '1 G-4 2 #380' 1380' Contingent-Packer w/Vent valve 3 12,573' 12,500' GLM Ill 4 14,165' ±4,000' GLM 112 S:csy snow 5 15,473' 15,250' GLM 113 I, Q966O'oa 6 16,784' 16,500' GLM 114 R Ns I- = 7 17,598' ±7,265' GLM 115 P_9 _ 8 ±8,160' ±7,800' GIM 116 fli I' 9 ±8,680' #8,300' GLM 117 10 ±9,101' 18,700' GLM 118 HK-1 11 ±9,131' ±8,729' Contingent-X Nipple _ 12 ±9,410' ±8,993' Bottom of FSP 13 10,068' 9,615' 3.25 Baker Model"D"Pkr. {1<.3 10,078' 9,624' 2.75 Otis"X"Nipple,size 2.75 10,086' 9,632' 3.00 Bell Guide 74 14 10,198' 9,737' 3.25 Baker Model"D"Pkr. F a FI!I lagged 1;., mX:Its@MOO.32t1K-4 10,206' 9,745' 2.62 Otis"Q"Nipple,size 2.625 y„ ;. = 10,212' 9,750' Mule Shoe i.'•,. .- ::. 13 ,.'' j,... ,; PERFORATION DETAIL t F$ .',',i Moo Zone Zone Top(MD) Btm(MD) (TVD) litre(WO) Amt. SPF Last Peri Date Present Condition S ' 5 G-2 9,370' 9,388' 8,955' 8,972' 18' 5 03/19/15 Open 8; Os G-4 9,478' 9,484' 9,057' 9,063' 6' 5 03/19/15 Open 1r F,1U9g.d°nG-5 9,610' 9,627' 9,182' 9,198' 17 , 5 03/19/15 Open ;+, az666®io.:w HK-5 Sqz 9,680' 9,681' 9,248' 9,249' 1' 4 11/2/1969 Sqz 100sxcmt. I Sqz 9,750' 9,751' 9,315' 9,315' 1' 4 10/30/1969 Sqz 75 sx am. No Joy en 11/14-t". • `� 1 - HK-1 9,820' 9,885' 9,381' 9,442' 65' 20 6/15/1992 Open f/Production th.pt,.during14 womnnr .. ' y HK-1 9,828' 9,862' 9,388' 9,420' 34' 5 03/19/15 Open ri', 'I HK-3 9,905' 9,950' 9,461' 9,503' 45' 16 6/15/1992 Openf/Production '"t ' HK-4 9,908' 9,932' 9,464' 9,486' 24' 5 03/19/15 Open '' HK-4 9,950' 10,065' 9,503' 9,611' 115' 16 6/15/1992 Open f/Production t�sp if HK-4 9,964' 9,986' 9,516' 9,537' 22' 5 03/19/15 Open ' ''''` '' .; . t HK-5 10,070' 10,190' 9,616' 9,730' 120' 16 Jul-75 Open 1/Production (' � HK-6 10,230' 10,260' 9,761 9,796' 30' 4 Jul-75 Open f/Production 15 *: , k. . I.. ' }'t' ' ' .:. ) i'. 4/29/75 D-27 collided w/l)-20 while drilling 17-1/2"surface hole.Communication to Inlet.Spoiled 500sx ofG cm( q 400' PDTD 10,430' TD=10,6 6 in 1)-27.Possible length of breach in 13-3/8"is 1188'to 1497'.I'encttalion in 13-20 9-5/8"(r71497'. MAX HOLE ANGLE=21°,@ 2100' 7/75 W()sqz'd 9-5/8"csg u, 1497'48.'I'oial cm(placed 650 sx. Updated: 12/21/16 by 1LL • • Dolly Verden Platform 1)-20 Current 12/19/2014 IIiu nrp:%half,Lt.c Dolly Varden tubing hanger,FMC-IC-ESP, 0-20 11 X 3 11 NS CI lift and rasp, 13 3/8 X 9 5/8 X 7 5/8 X 300 4 seal pocket,w/3" 2 7/8 type II OPV profile,2-3/8 CCI,Alloy material MITA,Bowen,3 1/8 SM FE X 3" Bowen Quick Union If r.pi u1 IIIMW Valve,swab,WKM-M, "'^"' , 31/8 SM FE,HWO, T-24 ,. • Valve,WKM-M,3 1/8 SM FE,w/ II r' 5"OMNI operator - ----,ri Valve,wing,WKM-M, ! - L' - 2 1/16 SM FE,MVO, ' 111 . �� T-24 r. ? P: 5 111 Valve,lower master,WKM-M, 1 .1.1 14 b 3 1/8 5M FE,HWO,T-24 _ in iii n Adapter,FMC-A-S-EC,11 SM rotating flange x 3 1/8 5M rotating top,300-4 pocket prep,2-CCI ports,3.266 centers Ill,, � . It I1...,, Multibowiwellhead assy, T"�a�� 1_,_��_ Cactus MOS-2 ��',_■ Valve,WKM-M,2 1/16 5M FE, 135/83Mx11SM,w/4- 2 1/16 SM SSB,prepped for i ill It 1 HWO,DO 7 5/8 mandrel hanger,and tubing hanger,9 5/8 HPS 1.1■ ( �� 41)0 h �.IN 1` bottom AA„AAA • a I' I Valve,WKM-M,2 1/16 5M FE, e —i I a i i • S . H Dolly Varden Platform Mooch BOP 12/19/2016 nnknll Alaska,Id.c lii 111111111111 • • 4.54' Hydril GK 17 S[8 Siyx) MOM Itl Ill Ii1 111111 1111 III 11I III I11 — •' yp�11 Variable rams UM. l 4.67' .1�' �- 27/8.5 [i ■1111,. 114/85dM Blind Rams lel A ilk lil Iii lillil lit Choke and Mil valves 0111011110 21/16 5M —� ri] SI111ir11ir 2 26' ;. F 1.,11 I' lil lil l!I lil 111 III 111111 III I!I Riser 135/85M FEX13S/85M FE III Iii III Ili 111 I!I 1111 III III III Spacer spool 135/8SM FE)(115M III lit 1i1lit • • •' oOOvOvx OOvO OUOUO0OOOOUO s O 'co: __ t -- O ': .. ,,, m ,, ,,, - N N NN SM sV V51 1SD 1� W 01 > n a a s U O 7 O 7 i3 a i7 g u •-1 N CO %1 VI 'NO "0 VN M vd Ilvl DV h VM 'OV .vy 09VV0 `t `t 0 w .2 gN , OOOOOOOO y • � � UO = = c c c u c ,' n n g o n mg n g n o 5 u a a a a a ' < < i y uY Yu yu T _ EEE £ E - ao 00 0 g w > daaa0 i 8 5 6 6 8 61' N # Y no O Ab; , OO 3 L c N M N, W UW I I, z i-1-t.;;t ,-x-.�111 J WW IAY I I aY a0 r7•,. ,}y DO COU I � U ,I ::I, 8 K 00. (/) s ., R C. .•"'l .1I -•4 NN III■ :"'(L! 1IUIIEITD � MO mH CO Wk a a 0 z • F z o O Z Uw a3z CD ` _ Dj ( ow H � jL�11 a. A Z 2 z -a LL < U E ' WOC S z U qt o , _ f�� O � � � w �C r Li- z , CL Lu in • m z I— o D W 0 MINEk • B" 00000 0 0 0 0 O U O U O U O D U O D U 0 ci a V 13 N M .-1 ~ N V is09 g 5 } S 5 F V N c O f 2 E 2 ii a 6 a a a a U U U U U U U U t N M V N CI N N M V ut O1 .-1 ✓ O V V O S V V V U V V V V V V V V 0 0 0 0 pp�O O O O O O O w O y }l N c c 7 7 4 U C A fcU n ? c C �C C A rc9 O R 0 n o n a n N•sa c C > u 4..;o v O O O 1 O O aQ1i Y t 3 t` L 2 E E E E E ; _e � [5 o. 0 0 0 0 0 0 0 0 0 0 a c t . > daaaa ; = i` 566656666 gra `o c• c .'.f s 0g ° LL t5 6 v O N On n. oo ..• a.I XI zz 1-•- , ,;-•-1 R J n c0 4 o IO.j `t -o ,..)64 U [L> W U O K f > X o w2 ,. � a . a y . 10 1 ......._ _ - .. 'L 7 C'i r 1 i a ,. [{ Epri 0, W a J—U k a p < 0 E- cnO Zoz _ Q p J ate0 J Z _ 2WzQ 0005- 1 0 ~Q S f_t , � w0C7 m J _jDJ 0a2ZI 0 0 1.7., tn•.. gNIL LL Z ❑ Vk:. ,tk: m L Q t_ _._._____±___t._ 0 F- p J ILD 0 0 S Moncla Rig 404 BOP Test Procedure uacnrpAbdo,i.i.c Attachment#1 Attachment #1 Hilcorp Alaska, LLC- BOP Test Procedure: Moncla Rig 404, WO Program—Oil Producers, Water Injectors Pre Rig Move 1) Blow down well,bleed gas to Well Clean Tank that is vented thru flare to atmosphere 2) Load well with FIW to kill well. • Note: Fluid level will fall to a depth that balances with reservoir pressure. 3) Shoot fluid level at least 24 hours before moving on well. 4) Shoot fluid level again,right before ND/NU. Confirm that well is static. Initial Test(I.e.Tubing Hanger is in the Wellhead) If BPV profile is good 1) Set BPV. ND Tree. NU BOP. 2) MU landing joint. Pull BPV. Set 2-way check in hanger. 3) Space out test joint so end of tubing(EOT)is just above the blind rams. 4) Set slips,mark same. Test BOPE per standard test procedure. If the tubing hanger won't pressure test due to either a penetrator leak or the BPV profile is eroded and/or corroded and BPV cannot be set with tree on.Profile and/or landing threads must be prepped while tree is off.Worst Case: BPV profile and landing threads are bad. 1) Attempt to set BPV through tree. If unsuccessful,shoot fluid level. 2) If fluid level is static from previous fluid level shots,notify Hilcorp Anchorage office that the well is static and the tree must be removed with no BPV.As approved in the sundry,proceed as follows: a) ND tree with no BPV b) Inspect and prepare BPV profile to accept a 2-way valve,or prepare lift-threads to accept landing Joint to hold pressure. If well is a producer and the culprit is scale,attempt to clean profile with Muriatic acid and a wire brush or wheel. c) Set 2-way check valve by hand,or MU landing(test)joint to lift-threads d) For ESP wells-Ensure that cap is on cable penetrator e) NU BOP. Test BOPE per standard procedure. 3) If both set of threads appear to be bad and unable to hold a pressure test and/or a penetrator leaks, notify Operations Engineer(Hilcorp),Mr.Guy Schwartz(AOGCC)and Mr.Jim Regg(AOGCC)via email explaining the wellhead situation prior to performing the rolling test. AOGCC may elect to send an inspector to witness. As outlined and approved in the sundry,proceed as follows: a) Nipple Up BOPE b) With stack out of the test path,test choke manifold per standard procedure c) Conduct a rolling test: Test the rams and annular with the pump continuing to pump,(monitor the surface equipment for leaks to ensure that the fluid is going down-hole and not leaking anywhere at surface.) d) Hold a constant pressure on the equipment and monitor the fluid/pump rate into the well. Record the pumping rate and pressure. e) Once the BOP ram and annular tests are completed,test the remainder of the system following the normal test procedure(floor valves,gas detection,etc.) • • Moncla Rig 404 BOP Test Procedure Attachment#1 Ililrorr Aln‘kn,I.IA: f) Record and report this test with notes in the remarks column that the tubing hanger/BPV profile/ penetrator wouldn't hold pressure and rolling test was performed on BOP Equipment and list items, pressures and rates. 4) Pull hanger to surface. (Requires tubing cuts as necessary to free tubing). CBU to displace annulus and tubing with kill weight fluid. 5) If a rolling test was conducted,remove the old hanger,MU new hanger or test plug to the completion tubing. Re-land hanger(or test plug)in tubing head. Test BOPE per standard procedure. Subsequent Tests(I.e.Test Plug can be set In the Tubing-head) 1) Remove wear bushing. a) Use inverted test plug to pull wear busing. MU to Joint of tubing. b) Thread into wear bushing c) Back out hold down pins d) Pull and retrieve wear bushing. 2) Break off test plug and invert same-RIH with test plug on joint of tubing. Install a pump-in sub w/test line plus an open TIW or lower Kelly valve in top of test joint w/open IBOP. 3) Test ROPE per standard procedure. STANDARD ROPE TEST PROCEDURE(after 2-way check or test plug is set) 1) Fill stack and all lines with rig pump-install chart recorder on test line connected to pump-in sub below safety valve and IBOP in test joint assembly. 2) Note: When testing,pressure up with pump to desired pressure,close valve on pump manifold to trap pressure and read same with chart recorder(test pressures will be indicated in Sundry). 3) Referencing the attached schematics test rams and valves as follows. a) Close ft valve on standpipe manifold,close valves 1,2,10 on choke manifold and close the annular preventer,open safety valve on top of test jt and close IBOP. Pressure test to 250 psi for 5 minutes and 2,500 psi high for 5 minutes. If passes after 5 minutes on each,bleed off pressure back to tank and open annular. b) Close pipe rams and open annular preventer,close safety valve and open IBOP on test Joint,close outside valve on kill side of mud cross,open 15`valve of standpipe,close valves 3,4&9 on choke manifold,open valves 1&2 on choke manifold. Test to 250 psi for 5 minutes and 3,000 psi high for 5 minutes. If passes after 5 minutes on each,bleed off pressure back to tank. c) Test Dual Rams. If the well has dual tubing,and dual rams are installed in the stack,test the dual rams by picking up two test joints with dual elevators and lowering them into stack and position them properly in the dual rams. Close rams. Test to 250 psi for 5 minutes and 3,000 psi for 5 minutes. If passes after 5 minutes on each,bleed off pressure back to tank. d) Close inside valve/open outside valve on kill side of mud cross,close valves 5&6/open valves 3&4 on choke manifold. Test to 250 psi for 5 minutes and 3,000 psi for 5 minutes. If passes after 5 minutes on each,bleed off pressure back to tank. e) Close manual and super choke/open valves 5&6 on choke manifold. Pressure up to^ 1200 psi and bleed off 200—300 Ifs recording change and stabilization. If passes after 5 minutes,bleed of pressure back to tank. f) Close HCR(outside valve on choke side of mud cross),open manual&super choke. Test to 250 psi for 5 minutes and 3000 psi for 5 minutes. If passes after 5 minutes on each,bleed off pressure back to tank. • • Moncla Rig 404 BOP Test Procedure Attachment#1 1111rorp A11148,1.11 g) Close inside valve/open outside valve(HCR)on choke side of mud cross. Test to 250 psi for 5 minutes and 3000 psi for 5 minutes. If passes after 5 minutes on each,bleed off pressure back to tank. h) Ensure all pressure is bled off-open pipe rams and pull test joint leaving test plug/2-way check in place. Close blind rams and attach test line to valve 10 on choke manifold,close valve 7&8/open valve 10 on choke manifold. Test to 250 psi for 5 minutes and 3000 psi for 5 minutes. If passes after 5 minutes on each,bleed off pressure back to tank. i) Test additional floor valves(TIW or Lower Kelly Valve)and IBOPs as necessary. STANDARD TEST PROCEDURE OF CLOSING UNIT(ACCUMULATOR) 1) This is a test of stored energy. Shut off all power to electric and pneumatic pumps. 2) Record"Accumulator Pressure". It should be+/-3,000 psi. 3) Close Annular Preventer,the Pipe Rams,and HCR. Close 2" set of pipe rams if installed(e.g.dual pipe rams). Open the lower pipe rams to simulate the closing volume on the blinds. 4) Allow pressures to stabilize. 5) While stabilizing: Record pressure values of each Nitrogen bottle and average over the number of bottles. (i.e. Report might read"10 bottles at 2,150 psi"). 6) After accumulator has stabilized,record accumulator pressure again. This represents the pressure and volume remaining after all preventers are closed. (The stabilized pressure must be at least 200 psi above the pre- charge pressure of 1,000 psi). 7) Turn on the pump and record the amount of time it takes to build an additional 200 psi on the accumulator gauge. This is usually+/-30 seconds. 8) Once 200 psi pressure build is reached,turn on the pneumatic pumps and record the time it takes for the pumps to automatically shut-off after the pressure to builds back to original pressure(+/-3,000 psi). Note: Make sure the electric pump is turned to"Auto",not"Manual"so the pumps will kick-off automatically. 9) Open all rams and annular and close HCR to place BOPE back into operating position for well work. 10) Fill out AOGCC report. FINAL STEP,FINAL CHECK 1) Test Gas Alarms 2) Double check all rams and valves,for correct operating position 3) Fill out the AOGCC ROPE Test Form(10-424)in Excel Format and e-mail to AOGCC and Juanita Lovett. Document both the rolling test and the follow up tests. • S .. .. . . . .. . . . . § kms # 20 \ J2 • a 072 \ 2 022 / \ < k0. E0 « � o c -a S f % \ ( k arc 4 ±f H 2 0 � " \ � i2E P P a. 0. � § q ® a) e / � X22 0 k O § $ �» Ft 2 J @ a) 0RI \ 10 a) / \ n & I- k �0. k 2 E e O. Q a\ o 0 � ® o C a \ / 0 2 / \ \ % 2 E % ° o m 2 O k -a a ) 2 ± / m \ \ E # k C `� Cl) 7 - 2 2 0 --— c W g m / \ / e k 2 / 4 0. \} / u. / . QR % G . . .. . . . . . . .. . . . . E 0 77) ? $ q 3 ® \ ® J < p CO C § •\ CL U) £ \ w U k U) o � � ---. . . < EL' « _ S . \ \ w 2 & 13 [ /3 \ .0 c *o ° 0. / 0 $ \ \ 0. 0.. �� I/% cv THE STATE Alaska Oil and Gas 4`1 OfA T ® SKA Conservation Commission = _=_ 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279.1433 ®F ALAS' Fax: 907.276.7542 www.aogcc.alaska.gov November 30, 2015 Mr. Stan Golis Operations Manager—CI Offshore Hilcorp Alaska, LLC P.O. Box 244027 Anchorage, AK 99524-4027 RE: No-Flow Verification SCANNED Trading Bay Unit D-20 PTD 1690950 Dear Mr. Golis: On November 16, 2015 an Alaska Oil and Gas Conservation Commission (AOGCC) Petroleum Inspector witnessed a no-flow test of Trading Bay Unit D-20 located on the Dolly Varden Platform in Cook Inlet. The well is operated by Hilcorp Alaska, LLC (Hilcorp). The AOGCC Inspector confirmed that the proper test equipment — as outlined in AOGCC Industry Guidance Bulletin 10-004 — was rigged up on Trading Bay Unit D-20 prior to the test. The well performance was monitored for approximately five hours with alternating open flow and shut in periods. The resulting gas flow rate at the end of each 1.5-hour flow monitoring period was below the regulatory limit; no liquids were produced during the test. The passing no-flow test means TBU D-20 may be produced without a subsurface safety valve. A fail-safe automatic surface safety valve system capable of preventing uncontrolled flow must be maintained in proper working condition in this well as required in 20 AAC 25.265. The subsurface safety valve must be returned to service if Trading Bay Unit D-20 demonstrates an ability to flow unassisted to surface. Any cleanout, perforating or other stimulation work in this well will necessitate a subsequent no flow test. Please retain a copy of this letter on the Dolly Varden Platform. Sincerely, ictiALQ E Re James B. Regg Petroleum Inspection Supervisor cc: P. Brooks AOGCC Inspectors STATE OF ALASKA AICA OIL AND GAS CONSERVATION COMADION I REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon ❑ Plug PerforationS❑ Fracture Stimulate ❑ Pull Tubing❑ Operations shutdown ❑ Performed: Suspend ❑ Perforate ❑ Other Stimulate 0 (Acid) ising❑ Change Approved Program ❑ Plug for Redrill ❑ Perforate New Pool ❑ Repair Well ❑ Re-enter Susp Well❑ Other: El 2.Operator 4.Well Class Before Work: 5. Permit to Drill Number: Name: HilcorpAlaska,LLC Development❑ Exploratory 169-095 i P rY ❑ 3.Address: 3800 Centerpoint Drive,Suite 1400 Stratigraphic❑ Service ❑ 6.API Number: Anchorage,AK 99503 50-733-20203-00 r 7.Property Designation(Lease Number): 8.Well Name and Number: ADL0018729 . Trading Bay Unit/D-20 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pool(s): , , N/A McArthur River Field/Middle Kenai G&Hemlock Oil Pools 11. Present Well Condition Summary: Total Depth measured 10,506 t feet Plugs measured N/A feet.11 t t E I true vertical 10,028 , feet Junk measured 10,068&10,198 feet NOV 1 7 20i;; Effective Depth measured 10,045 feet Packer measured 341, 10,068,10,198 feet true vertical 9,593 feet true vertical 341,9,615,9,737 feet LOGCC Casing Length Size MD TVD Burst Collapse Structural Conductor 400' 33" 400' 399' Surface 3,006' 13-3/8" 3,006' 2,905' 3,090 psi 1,540 psi Production 9,674' 9-5/8" 9,674' 9,242' 5,750 psi 3,090 psi Liner 9,467' 7-5/8" 9,467' 9,047' 6,890 psi 4,790 psi Liner 1,014' 7" 10,480' 10,003' 8,160 psi 7,020 psi Perforation depth Measured depth 9,370-10,260 feet True Vertical depth 8,955-9,796 feet WANED FEB 0 9 "lc' Tubing(size,grade,measured and true vertical depth) 2-7/8"&3-1/2" 6.5#&9.2#/L-80 366'325'&9,309'(MD) 366',325'&8,897'(TVD) Dual ESP Pkr 341'(MD)341'(TVD) Packers and SSSV(type,measured and true vertical depth) Model"D"Pkr 10,068'(MD)9,615'(TVD) Model"D"Pkr 10,198'(MD)9,737'(TVD SSSV 315'(MD)315'(TVD) 12.Stimulation or cement squeeze summary: Intervals treated(measured): 9730'-9986' Treatment descriptions including volumes used and final pressure: 335 bbls FIW spearhead.Preflush-330 gallons WAW-5206/990 gallons Xylene mixture.3000 gallons 10%HCL Acid.85 bbls FIW displacement.Final pressures: Tubing-67 psi,9-5/8 76 psi, 13-3/8 19 psi 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 200 97 2120 114 118 Subsequent to operation: 199 42 1962 115 116 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations ❑ Exploratory El Development❑ a Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16.Well Status after work: Oil [ Gas ❑ WDSPL❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ 3USP❑ SPLUG❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: 315-609 Contact Stan W.Golis Email sgolisahilcorp.com Printed Name Stan W.Golis ` Title Operations Manger Signature 3, 7rCi W C Phone (907)777-8356 Date 11/16/2015 RBDMSt) NOV 10 2015 Form 10-404 Revised 5/2015 /z ,; N``' /Z/87/.'`— Submit Original Only Trading Bay Unit . H SCHEMATIC Well: D-20 HilcorpAlaska.LLC Completed: 03/22/15 RKB to TBG Head=41.8' CASING DETAIL Tree connection:4-1/6"5,000# SIZE TYPE WT GRADE CONN ID TOP BTM. < 4: * 33" Conductor Surf 400' 1 4,' 13-3/8" Surf Csg 61 K-55 Seal Lock 12.515 Surf 3006' +� 2 i' 9-5/8" Prod Csg 40 N-80 Butt 8.835 Surf 4390' A Ko 3 } },, 43.5 8.755 4390' 5204' I a. a<, DV r "‘'� Collar 5204' 5206' i;.>' 43.5 N-80 8.755 5206' 6156' , 1iS-95 Butt 6156' 7080' 9-5/8" Prod Csg 47 8.681 7080' 9072' AR-95 Seal Lock 9072' 9674' ' j 7-5/8" Liner 29.7 L-80 SLIJ-II 6.875 Surf 9,467' �, 7" Liner 29 N-80 X-Line 6.185 9463' 10,480' TUBING DETAIL 3-1/2" 9.2# L-80 Supermax 2.992 Surf 325' 4 2-7/8" 6.5# L-80 8rd EUE 2.441 325' 366' 1 5 3-1/2" 9.2# L-80 Supermax 2.992 366' 9,309' 6 IN 7JEWELRY DETAIL Yr p. 3 - 8 NO. Depth ID Item g 0 CIW 4-1/2"EUE 8rd X Butt Tbg.Hanger. >,, ' G-2 1 315' SSSV J ' r _ 2 341' 2.441 7-5/8"Dual ESP Packer w/Vent valve ULL r'' G-4 3 356' 2.313 X Nipple w/collar , 4 9,309' - Discharge,Bolt-On r; G-5 5 9,310' Pump(x2)513 Series,093 Stage y'ICsg Shoe 6 9,352' - Intake 9660'DIL 7 9,371' - Motor 562,340 H/3360V/61A 5118 8 9,407' Anode Centrilizer °°° 9 10,068' 3.25 Baker Model"D"Pkr. ma k! ` ; 10,078' 2.75 Otis"X"Nipple,size 2.75 10,086' 3.00 Bell Guide HK-1 10 10,198' 3.25 Baker Model"D"Pkr. 10,206' 2.625 Otis"Q"Nipple,size 2.625 10,212' Mule Shoe K-3 Brief Details&Info:To date Spudded D-20 on 9/20/69.TD @ 10,506'on 10/25/69.Completed&RR on 11/06/69. •Hole Section MWT: •Approximate Rotating hrs: Fill tagged ,on 03116/15 0210,046 ,,, K4 o 17-1/2"to 3050' 9,9 to 10 ppg o 33" 60 hrs ? CfpG1o 12-1/4"to 9,748' 9.8 to 10 ppg o 13-3/8" 285 hrs o 8-1/2"to 10,506 o 9-5/8" 51 hrs 0 JI n o 7" 16hrs s PERFORATION DETAIL ''' ,' Top Top Btm 17, r2' I, - Zone (MD) Btm(MD) (TVD) (TVD) Amt. SPF Last Perf Date Present Condition 1 , , - W G-2 9,370' 9,388' 8,955' 8,972' 18' 5 03/19/15 Open G-4 9,478' 9,484' 9,057' 9,063' 6' 5 03/19/15 Open ; Fill tagged on - 8/26/96@10,201' `HK-5 G-5 9,610' 9,627' 9,182' 9,198' 17 5 03/19/15 Open Sqz 9,680' 9,681' 9,248' 9,249' 1' 4 11/2/1969 Sqz 100 sx cmt. No Joy on 24116"t6g : -&I <+ Sqz 9,750' 9,751' 9,315' 9,315' 1' 4 10/30/1969 Sqz 75 sx cmt. thru pkr.dudng Wo In 11/63 ,._ -'*v 10 HK-1 9,820' 9,885' 9,381' 9,442' 65' 20 6/15/1992 Open f/Production .44% 1"•"1: 9,828' 9,862' 9,388' 9,420' 34' 5 03/19/15 Open �.- I .H HK-3 9,905' 9,950' 9,461' 9,503' 45' 16 6/15/1992 Open f/Production HK-4 9,908' 9,932' 9,464' 9,486' 24' 5 03/19/15 Open 1 tc HK-4 9,950' 10,065' 9,503' 9,611' 115' 16 6/15/1992 Open f/Production 1HK-4 9,964' 9,986' 9,516' 9,537' 22' 5 03/19/15 Open 4 K-6 HK-5 10,070' 10,190' 9,616' 9,730' 120' 16 Jul-75 Open f/Production v. ', HK-6 10,230' 10,260' 9,767' 9,796' 30' 4 Jul-75 Open f/Production v A 4/29/75 D-27 collided w/D-20 while drilling 17-1/2"surface hole.Communication to Inlet.Spotted 500sx of G cmt @ 400' PBTD=10,430' TD=10,506 in D-27.Possible length of breach in 13-3/8"is 1488'to 1497'.Penetration in D-20 9-5/8"@ 1497'. MAX HOLE ANGLE=21°,@ 2100' 7/75 WO sqz'd 9-5/8"csg @ 1497'4x.Total cmt placed 650 sx. Updated: 04/21/15 by JLL • • Hilcorp Alaska, LLC Well Operations Summary � � 0° •� iz/' I Well Name Rig API Number Well Permit Number Start Date End Date D-20 Pumping 50-733-20203-00 169.005 11/3/15 11/3/15 Daily Operations: 11/03/2015-Tuesday Rig hoses to chemical tanks and move HP hose to D-20. Safety meeting. Pressure test to swab valve - 500 Low/2000 High. Fill well bore with 335 bbls FIW. Pump preflush -330 gallons WAW-5206/990 gallons Xylene mixture.Tubing- 5 psi, 9-5/8 63 psi, 13-3/8 23 psi. Pump 3000 gallons 10% HCL Acid.Tubing- 66 psi, 9-5/8 62 psi, 13-3/8 19 psi, 2.2 bpm. ... • Pump 85 bbls FIW displacement.Tubing- 67 psi, 9-5/8 76 psi, 13-3/8 19 psi, 1.9 bpm. Soak for 6 hours then return to production. ti OF T � • • ew\��V/j��cv THE STATE Alaska Oil and Gas ��., ,... � of I ASKA. Conservation Commission :_ ft - 2 ,_ y;_ 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 � � Main: 907.279.1433 o�'ALAS*- Fax: 907.276.7542 www.aogcc.alaska.gov Dan Marlowe �� t �� ' Operations Engineer SkD 9 Hilcorp Alaska, LLC I to 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: McArthur River Field, Hemlock Oil and Middle Kenai G Oil Pools, TBU D-20 Sundry Number: 315-609 Dear Mr. Marlowe: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, --'let.i V.C' Cathy P. oerster Chair DATED this /at of October, 2015 Encl. RBDMS 44A !Ci 151015 • • RECEIVED STATE OF ALASKA SEP 2 5 2015 ALASKA OIL AND GAS CONSERVATION COMMISSION 16 I L3) IS APPLICATION FOR SUNDRY APPROVALS AOGCC 2Q AAC 25.2$Q 1.Type of Request: Abandon❑ Plug Perforations❑ Fracture Stimulate ❑ Pull Tubing ❑ Operations shutdown ❑ Suspend❑ Perforate ❑ Other Stimulate 0 (Acid) Alter Casing ❑ Change Approved Program ❑ Plug for Redrill❑ Perforate New Pool ❑ Repair Well ❑ Re-enter Susp Well ❑ Other: ❑ 2.Operator Name: 4.Current Well Class: 5. Permit to Drill Number: Hilcorp Alaska,LLC ' Exploratory ❑ Development 0 • 169-095 3.Address: 3800 Centerpoint Drive,Suite 1400Stratigraphic ❑ Service ❑ 6.API Number: Anchorage,AK 99503 50-733-20203-00 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 0 I Trading Bay Unit/D-20 - 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL0018729 i McArthur River Field/Middle Kenai G&Hemlock Oil Pools 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD(ft): Effective Depth TVD(ft): Plugs(measured): Junk(measured): 10,506 10,028 10,045 9,593 N/A 10,068&10,198 Casing Length Size MD TVD Burst Collapse Structural Conductor 400' 33" 400' 399' Surface 3,006' 13-3/8" 3,006' 2,905' 3,090 psi 1,540 psi Production 9,674' 9-5/8" 9,674' 9,242' 5,750 psi 3,090 psi Liner 9,467' 7-5/8" 9,467' 9,047' 6,890 psi 4,790 psi Liner 1,017' 7" 10,480' 10,003' 8,160 psi 7,020 psi Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: 2-7/8" Tubing Grade: 6.5#/L-80 Tubing MD(ft): 9,370-10,260 8,955-9,796 3-1/2" 9.2#/L-80 366',325'&9,309' Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): Dual ESP Pkr, Model"D"Pkr(x2)&SSSV + 341'(MD)341'(TVD)10,068'(MD)9,615'(TVD)10,198'(MD)9,737'(TVD)&315'(MD)315'(TVD) 12.Attachments: Description Summary of Proposal 0 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic U Development CI • Service ❑ 14.Estimated Date for 15.Well Status after proposed work: Commencing Operations: 10/12/2015 OIL 0• WINJ ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ Commission Representative: GINJ ❑ Op Shutdown El Abandoned ❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Dan Marlowe Email dmarlowe(a8hilcorp.com Printed Name Dan Marlowe / y�, Title Operations Engineer --all• ae., /'i6 f4- Q Signature ‘ Phone (907)283-1329 Date 9/25/2015 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 3/5 — (009 Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test Cl Location Clearance ❑ Other: Spacing Exception Required? Yes ❑ No Subsequent Form Required: _' ti,h'"i RBDMS okl tCle 15 2015 APPROVED BY Approved by: (4647/) 9),...CA,..pgiµ--ms COMMISSIONER THE COMMISSION Date: lQ — /3 —(S !o'T!' A i'/ 1A0)15-- �'`� `L,tD �'' /\ Submit Form and Form 10-403 Revised 5/2 5 Or� ,p id for 12 months from the date of approval. Attachments in Duplicate • Well Work Plan Well: D-20 Hilcoru Alaska,LL Date:09/25/2015 Well Name: D-20 API Number: 50-733-20203-00 Current Status: ESP Lifted Producer Leg: B-1 (SE Corner) Estimated Start Date: 10/12/15 Rig: N/A Reg. Approval Req'd? Date Reg. Approval Rec'vd: Regulatory Contact: Juanita Lovett Permit to Drill Number: 169-095 First Call Engineer: Dan Marlowe (907) 283-1329 (0) (907) 398-9904 (M) Second Call Engineer: Ted Kramer (907) 777-8420 (0) (985) 867-0665 (M) Current Bottom Hole Pressure: 2,820 psi @ 8,990' TVD ESP Intake Gauge SIBHP Maximum Expected BHP: 4,820 psi @ 8,990' TVD Well SIBP of 2,820 psi plus 2000 psi pump pressure. Max.Anticipated Surface Pressure: 2,000 psi treatment pump pressure limit Well Summary The D-20rd is an oil well producer which is currently on ESP artificial lift. Total fluid production from this well has declined since the March 2015 work over. This decrease is believed to have been caused by scale formation in the well bore and perforation tunnels. Well Objective Hilcorp plans to pump an acid soak down the production tubing and across the perforations to clean up any scale deposition. Procedure: 1. MIRU pumping equipment. 2. Shut down ESP. 3. Pressure test surface lines to 2,090 psi (treatment pump relief valve limit). 4. Mix chemicals and pump in the following sequence: a. Open back side, pump FIW down tubing taking returns up the annulus. b. Pump 1320 gallons of pre-flush (330 gallons WAW-5206 mutual solvent blended with 990 gallons of Xylene. ); . Pump +/-3,000 gallons of±10% Hydrochloric Acid d. Close the 9-5/8" casing return line and bullhead the chemical pills across the perfs with >_85 barrels of FIW for displacement. 5. Shut down pump and let acid soak for >_6 hours. 6. RD Pumping equipment. 7. Return well to production. 8. Schedule a No-Flow test within 14 days of stable production. Attachments: 1. As-built Schematic 0 • Trading Bay Unit r H SCHEMATIC Well: D-20 Itiicorp Alaska,LLC Completed: 03/22/15 RKB to TBG Head=41.8' CASING DETAIL Tree connection:4-1/6"5,000# SIZE TYPE WT GRADE CONN ID TOP BTM. ( � I 33" Conductor Surf 400' 1 - 13-3/8" Surf Csg 61 K-55 Seal Lock 12.515 Surf 3006' \: 4/7 , • 2 .' 9-5/8" Prod Csg 40 N-80 Butt 8.835 Surf 4390' El 3 43.5 8.755 4390' 5204' I. ;.. DV 5204' 5206' i; Collar I .'2 43.5 N-80 8.755 5206' 6156' ", S-95 Butt 6156' 7080' ?' 9-5/8" Prod Csg 47 8.681 7080' 9072' AR-95 Seal Lock 9072' 9674' 7-5/8" Liner 29.7 L-80 SLID-II 6.875 Surf 9,467' 7" Liner 29 N-80 X-line 6.185 9463' 10,480' I. TUBING DETAIL 3-1/2" 9.28 L-80 Supermax 2.992 Surf 325' 4 2-7/8" 6.58 L-80 8rd EUE _ 2.441 325' 366' IN 5 3-1/2" 9.2# L-80 Supermax 2.992 366' 9,309' iir 6 7 JEWELRY DETAIL 8 ' 8 NO. Depth ID Item o 2 5' 0 CIW 4-1/2"EUE 8rd X Butt Tbg.Hanger. o8 . G2 81 , 1 315' SSSV tLL , 2 341' 2.441 7-5/8"Dual ESP Packer w/Vent valve G-4 3 356' 2.313 X Nipple w/collar 4 9,309' - Discharge,Bolt-On . G-5 5 9,310' - Pump(x2)513 Series,093 Stage ,csgsnoe 6 9,352' - . Intake @ 9660'DIL 7 9,371' - Motor 562,340 H/3360V/61A 1M '7= = 8 9,407' - Anode Centrilizer „222 _ = 9 10,068' 3.25 Baker Model"D"Pkr. moo, . 10,078' 2.75 Otis"X"Nipple,size 2.75 10,086' 3.00 Bell Guide = HK-1 10 10,198' 3.25 Baker Model"D"Pkr. 10,206' 2.625 Otis"Q"Nipple,size 2.625 10,212' Mule Shoe --IK-3 Brief Details&Info:To date Spudded D-20 on 9/20/69.TD @ 10,506'on 10/25/69.Completed&RR on 11/06/69. •Hole Section MWT: •Approximate Rotating hrs: NM •. Fill tagged o 17-1/2"to 3050' 9.9 to 10 ppg o 33" 60 hrs on 03/18/15 @ 10,045'.iK-4 o 12-1/4"to 9,748' 9.8 to 10 ppg 0 13-3/8" 285 hrs C3... - o 8-1/2"to 10,506 o 9-5/8" 51 hrs o 7" 16 hrs 9 _ PERFORATION DETAIL g = Zone Top Btm(MD) Top Btm Amt. SPF Last Perf Date Present Condition (MD) (TVD) (ND) G-2 9,370' 9,388' 8,955' 8,972' 18' 5 03/19/15 Open G-4 9,478' 9,484' 9,057' 9,063' 6' 5 03/19/15 Open Fill tagged on 8/28/88@10,201' ==HK-5 G-5 9,610' 9,627' 9,182' 9,198' 17 5 03/19/15 Open Sqz 9,680' 9,681' 9,248' 9,249' 1' 4 11/2/1969 Sqz 100 sx cmt. No Joy on 24116"lbg • Sqz 9,750' 9,751' 9,315' 9,315' 1' 4 10/30/1969 Sqz 75 sx cmt. thru pkr.during . 10 HK-1 9,820' 9,885' 9,381' 9,442' 65' 20 6/15/1992 Open f/Production wolnll/ea ' HK-1 9,828' 9,862' 9,388' 9,420' 34' 5 03/19/15 Open 0:" HK-3 9,905' 9,950' 9,461' 9,503' 45' 16 6/15/1992 Open f/Production wl - HK-4 9,908' 9,932' 9,464' 9,486' 24' 5 03/19/15 Open -- HK-4 9,950' 10,065' 9,503' 9,611' 115' 16 6/15/1992 Open f/Production HK-4 9,964' 9,986' 9,516' 9,537' 22' 5 03/19/15 Open `:CFIK-6 HK-5 10,070' 10,190' 9,616' 9,730' 120' 16 Jul-75 Open f/Production � HK-6 10,230' 10,260' 9,767' 9,796' 30' 4 Jul-75 Open f/Production 4`. �' N. 4/29/75 D-27 collided w/D-20 while drilling 17-1/2"surface hole.Communication to Inlet.Spotted 500sx of G cmt @ 400' in D-27.Possible length of breach in 13-3/8"is 1488'to 1497'.Penetration in D-20 9-5/8"@ 1497'. PBTD=10,430' TD=10,506' MAX HOLE ANGLE=21°,@ 2100' 7/75 WO sqz'd 9-5/8"csg @ 1497'4x.Total cmt placed 650 sx. Updated: 04/21/15 by J LL STATE OF ALASKA ALA.,..A OIL AND GAS CONSERVATION COME. JION REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon ❑ Repair Well ❑ Plug Perforations ❑ Perforate 0 Other 0 Install ESP wAjK� Performed: Alter Casing 0 Pull Tubing❑✓ Stimulate-Frac ❑ Waiver❑ Time Extension❑ Change Approved Program 0 Operat.Shutdown❑ Stimulate-Other ❑ Re-enter Suspended Well0 2.Operator 4.Well Class Before Work: 5.Permit to Drill Number: Name: Hilcorp Alaska,LLC Development El Exploratory 0 169-095 3.Address: 3800 Centerpoint Drive,Suite 1400 Stratigraphic❑ Service 0 6.API Number: Anchorage,AK 99503 50-733-20203-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL0018729 Trading Bay Unit/D-20 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): McArthur River Field/Middle Kenai G&Hemlock Oil Pools 11.Present Well Condition Summary: Total Depth measured 10,506 feet Plugs measured N/A RECEIVED true vertical 10,028 feet Junk measured 10,068&10,198 feet APR 2 1 2015 Effective Depth measured 10,045 feet Packer measured 341',10,068',10,198' feet true vertical 9,593 feet true vertical 341'•9,615',9,737' feet AOG CC Casing Length Size MD TVD Burst Collapse Structural Conductor 400' 33" 400' 399' Surface 3,006' 13-3/8" 3,006' 2,905' 3,090 psi 1,540 psi Production 9,674' 9-5/8" 9,674' 9,242' 5,750 psi 3,090 psi Liner 9,467' 7-5/8" 9,467' 9,047' 6,890 psi 4,790 psi Liner 1,017' 7" 10,480' 10,003' 8,160 psi 7,020 psi Perforation depth Measured depth 9,370-10,260 feet SCANNED APR 2 2015 True Vertical depth 8,955-9,796 feet Tubing(size,grade,measured and true vertical depth) 2-7/8" 6.5#/L-80 366'(MD) 366'(ND) 3-1/2" 9.2#/L-80 325'(MD)&9,309'(MD) 325'(TVD)&8,897'(ND) Packers and SSSV(type,measured and true vertical depth) Dual ESP Packer 341'(MD)341'(ND) Model D Packer 10,068'(MD)(ND) Model D Packer 10,198'(MD)(ND) SSSV 315'(MD)315'(ND) 12.Stimulation or cement squeeze summary: Intervals treated(measured): N/A Treatment descriptions including volumes used and final pressure: N/A 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 0 0 55 0 Subsequent to operation: 285 74 2814 117 120 14.Attachments: 15.Well Class after work: Copies of Logs and Surveys Run Exploratory❑ Development0 Service El Stratigraphic ❑ Daily Report of Well Operations X 16.Well Status after work: Oil ❑., Gas ❑ WDSPL❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ❑ SUSP❑ SPLUG❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: 314$4 &1 Contact Dan Marlowe ,,, Email dmarlowec hilcorp.com Printed Name Dan Mar• r y A/l/p „fip'� Title Operations Engineer ifevidtep,— Signature �' I Phone (907)283-1329 Date 4/21/2015 10-4 Form 04 Revised 10/2012q�Y�02 3-/.3 _ RBDM� APR 2 2 2OlSSubmit Original Only tli/_117/ .__._... .._. Trading Bay Unit SCHEMATIC Well: D-20 Ililcorp Alaska,LLC Completed: 03/22/15 RKB to TBG Head=41.8' CASING DETAIL Tree connection:4-1/6"5,000# SIZE TYPE WT GRADE CONN ID TOP BTM. , 33" Conductor Surf 400' 1 , T 13-3/8" Surf Csg 61 K-55 Seal Lock 12.515 Surf 3006' ' 9-5/8" Prod Csg 40 N-80 Butt 8.835 Surf 4390' A .:. 3 43.5 8.755 4390' 5204' a DV 5204' 5206' ,• Collar 43,5 N-80 8.755 5206' 6156' : S-95 Butt 6156' 7080' 9-5/8" Prod Csg 47 8.681 7080' 9072' 1` AR-95 Seal Lock 9072' 9674' 7-5/8" Liner Wit--b'' 29.7 L-80 SLIJ-II 6.875 Surf 9,467' I 7" Liner 29 N-80 X-Line 6.185 9463' 10,480' Nltti-' TUBING DETAIL 73' 3-1/2" 9.2# L-80 Supermax 2.992 Surf 325' q 2-7/8" 6.5# L-80 8rd EUE 2.441 325' _ 366' 5 3-1/2" 9.2# L-80 Supermax 2.992 366' 9,309' 8 6 7 JEWELRY DETAIL II s.. 8 NO. Depth ID Item Sii-A G 2 0 CIW 4-1/2"EUE 8rd X Butt Tbg.Hanger. �s t '4 1 315' SSSV ml aN M 2 341' 2.441 7-5/8"Dual ESP Packer w/Vent Nent valve 440 G-4 3 356' 2.313 X Nipple w/collar No 4 9,309' _ - Discharge,Bolt-On `t) kil G-5 5 9,310' - Pump(x2)513 Series,093 Stage i krs9S • 6 9,352' Intake tti -y` la 9660'DIL 7 9,371' - Motor 562,340 H/3360V/61A ig tF VI. 8 9,407' - Anode Centrilizer 12°a rT �; 9 10,068' _ 3.25 Baker Model"D"Pkr. 8e 10,078' 2.75 Otis"X"Nipple,size 2.75 10,086' 3.00 Bell Guide HK-1 10 10,198' 3.25 Baker Model"D"Pkr. 10,206' 2.625 Otis"Cr Nipple,size 2.625 10,212' Mule Shoe - K-3 Brief Details&Info:To date Spudded D-20 on 9/20/69.10 @ 10,506'on 10/25/69.Completed&RR on 11/06/69. g•, _ •Hole Section MINT: •Approximate Rotating hrs: 1- iik Fn tagged 0 17-1/2"to 3050' 9.9 to 10 ppg o 33" 60 hrs 03/16/15 @ 10,045 . K.4 OA.on o 12-1/4"to 9,748' 9.8 to 10 ppg o 13-3/8" 285 hrs �+J' o 8-1/2"to 10,506 o 9-5/8" 51 hrs tip ii JI o 7" 16 hrs 9 PERFORATION DETAIL $ '01 Top Top Btm e - Zone (MD) Btm(MD) (TVD) (TVD) Amt. SPF Last Perf Date Present Condition G-2 9,370' 9,388' 8,955' 8,972' 18' 5 03/19/15 Open LL - G-4 9,478' 9,484' 9,057' 9,063' 6' 5 03/19/15 Open t Ivo.gg.a0a _ n G 5 9 610 9 627' 9 182' 9 198' 17 5 03/19/15 O e t to,zot K-5P Sqz 9,680' 9,681' 9,248' 9,249' 1' 4 11/2/1969 Sqz 100 sx cmt. NO Joy on 3-1H6"lbg ® JI Sqz 9,750' 9,751' 9,315' 9,315' 1' 4 10/30/1969 Sqz 75sxcmt. tn"'°"`during -' 10 HK-1 9,820' 9,885' 9,381' 9,442' 65' 20 6/15/1992 Open f/Production WO In 11/83 i - ' HK-1 9,828' 9,862' 9,388' 9,420' 34' 5 03/19/15 Open • HK-3 9,905' 9,950' 9,461' 9,503' 45' 16 6/15/1992 Open f/Production C''' HK-4 9,908' 9,932' 9,464' 9,486' 24' 5 03/19/15 Open --N.K HK-4 9,950' 10,065' 9,503' 9,611' 115' 16 6/15/1992 Open f/Production HK-4 9,964' 9,986' 9,516' 9,537' 22' 5 03/19/15 Open K-6 HK-5 10,070' 10,190' 9,616' 9,730' 120' 16 Jul-75 Open f/Production HK-6 10,230' 10,260' 9,767' 9,796' 30' 4 Jul-75 Open f/Production 4 .iA 4/29/75 D-27 collided w/D-20 while drilling 17-1/2"surface hole.Communication to Inlet Spotted 500sx of G cmt @ 400' in D-27.Possible length of breach in 13-3/8"is 1488'to 1497'.Penetration in D-20 9-5/8"@ 1497'. PBTD=10,430' TD=10,506' MAX HOLE ANGLE=21°,@ 2100' 7/75 WO sqz'd 9-5/8"csg @ 1497'4x.Total cmt placed 650 sx. Updated: 04/21/15 by JLL Hilcorp Alaska LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date D-20 50-733-20203-00 169-095 2/5/15 3/22/15 Daily Operations: 02/05/15-Thursday R/U & RUN KOOMEY LINES FROM KOOMEY UNIT TO BOP AREA. ASSIST CAMERON REP SET BPV& HOT BOLT TREE. N/D DRY HOLE TREE. R/D V-DOOR SLIDE. N/U 11'X 5M RISER, FLOW CROSS,3FT SPACER SPOOL&WING VALVES. SHUT DOWN DUE TO WINDS EXCEEDING 65 MPH. CONT'TO WINTERIZE. CONT'TO N/U DBL STACK RAMS&HYDRIL. TIGHTEN UP ALL NUTS ON BOPS. CONT'TO WINTERIZE AROUND RIG. CONT'TO GET RIG INTO COMPLIANCE. HOOK-UP KOOMEY LINES TO BOPS. SET V-DOOR SLIDE IN PLACE. 02/06/15-Friday CONTINUE HOOKING UP STEM HEATERS TO PUMP ROOM, RUNNING GLYCOL LINE THRU PUMP LINE BOX. ELECTRICIANS HOOKING UP REMOTE FROM RIG FLOOR TO ACCUMULATOR. FABRICATING RETURN LINE TO SHAKER FROM CIRCULATING MANIFOLD. CONTINUE WINTERIZING RIG EQUIPMENT AND GETTING RIG IN COMPLIANCE. R/U TEST EQUIPMENT. LAND TEST JT AND SCREW INTO HANGER. PRE-TEST 11'X 5M BOPS AND SURFACE EQUIPMENT AS PER PROCEDURES 250LOW/ 2500 HIGH, WHILE WAITING ON AOGCC REP TO ARRIVE TO BOP WITNESS TEST. 02/07/15-Saturday CONTINUE WINTERIZING RIG AND INSTALLING WIND WALLS WHILE WAITING ON AOGCC INSPECTOR TO ARRIVE. AOGCC WITNESS WAIVED BY MATT HERRERA. STARTED RIGGING TO TEST BOP'S. CONTINUED WINTERIZING AND TESTING BOP PIPE RAMS,ANNULAR AND RELATED EQUIPMENT TO 250 PSI LOW 2500 PSI HIGH ON CHART. PULL BACK PRESSURE VALVE AND INSTALL TWO WAY CHECK AND TEST BLIND RAMS TO 250 PSI LOW 2500 PSI HIGH FOR 5 MIN EACH ON CHART. RIG DOWN TEST EQUIPMENT AND PREPARE TO PULL HANGER TO RIG FLOOR. 02/08/15-Sunday PULL HGR TO RIG FLOOR AND LAYDOWN SAME. WRAP BOPS W/TARPS AND RE-ROUTE_HEATER DUCTS DUE TO ICING.C/0 DISCHARGE VALVE ON SUCTION MANIFOLD DUE fa-VA L V EBEING FROZE UP. INSTALL ELECTRIC CHROME-A-LOX HEATER IN WING BASKET DUE TO STANDPIPE MANIFOLD ICING UP. RU FILL UP LINE TO FLOW CROSS TO CONTIUOUSLY FILL HOLE TO KEEP CIRCULATING MANIFOLD FROM FREEZING UP. FINISH WINTERIZING RIG EQUIPMENT WHILE WAITNG FOR WIND TO DIE DOWN. 35-42 MPH. POOH W 10 JTS OF 3-1/2" KILL STRING AND LAYDOWN SAME. INSTALL MANUAL CHOKE ON DISCHARGE OF PUMP TO USE CONTINUOS FILL TO KEEP FLUID MOVING. SERVICE RIG& PERFORM SAFETY COMPLIANCE CHECKS. ATTEMPT TO POOH W/3-1/2 IBTC TBG W/NO SUCCESS. MCCOY TONGS WOULDN'T BREAK PIPE. SCARING/SLIPPING. MADE SEVERAL ATTEMPTS TO ADJUST BRAKES,CHANGE DIES ETC W/NO SUCCESS. R/D MCCOY TONGS& REMOVE FROM FLOOR.SET FOSTER TONGS ON FLOOR& R/U SAME. POOH W/3-1/2" IBTC KILL STRING. L/D& STRAP SAME. (92 JNTS TOTAL= 2,750' ). P/U WEAR BUSHING R/R TOOL&WEAR BUSHING. RIH &SET SAME. R/D RETURN LINE&N/D FLOW LINE RISER SPOOL. N/U RISER SPACER SPOOLS. GATHER BHA& M/U ON PIPE RACK. R/U AIR SLIPS. SWAP P.H.E.& PREP TO P/U BHA. Hilcorp Alaska LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date D-20 50-733-20203-00 169-095 2/5/15 3/22/15 Daily Operations: 02/09/15-Monday SERVICE RIG AND SAFETY COMPLIANCE CHECK. P/U & M/U BHA. FOUND POLLUTION PANS AROUND BOPS UNDER RIG FLOOR NOT SECURED. SECURE POLLUTION PANS,SEAL SAME AND RUN DRAIN LINES. FINISH M/U 8.50" BIT, (2) BOOT BASKETS, OIL/BUMPER JARS AND(4)4-3/4" DCS,STRAP AND RABBIT SAME. P/U 3-1/2" PH6 OUT OF V-DOOR AND TIH W/BHA. RABBIT AND STRAP SAME. REPAIR TONGS. CONT P/U 3-1/2" PH6 AND TIH. CONT TO P/U 3-1/2" PH6 OUT OF V- DOOR&TIH WI BHA. DRIFT&STRAP SAME.TAG CMT @ 4,043' DPM SET 5K DWN, P/U=54K. R/D HEATER ON S.E. CORNER OF PIPE RACK& MOVE SAME. R/D& MOVE CATWALK TO DRILLER SHACK. P/U DRILL LINE.SPOOL&SET IN PLACE ON S.E. CORNER OF PIPE RACK. INSTALL CUTTINGS TROUGH ON DUAL SHAKERS&SET CUTTING BOX UNDER SAME. REPLACE CATWALK, HEATER& R/U SAME. PULL HYDRAULIC HOSES FOR POWER SWIVEL POWER UNIT TO DERRICK LINES& R/U SAME. PULL AIR LINES FOR POWER SWIVEL CTRL BOX& R/U SAME.SWAP UNION ON MUD PUMP LINE. 02/10/15-Tuesday SERVICE RIG AND SAFETY COMPLIANCE CHECK. TROUBLESHOOT PROBLEM WITH PZ-9 PUMP. DRILL OUT CMT RETAINER AND CMT FROM 4,024'-4,113' DPM. PUMPING 3 BPM 200 PSI, ROTARY=60,TORQUE=2-3K, REV/OUT 1 TBG VOL EVERY CONNECTION. CONT'TO DRILL OUT CMT F/4,113'-T/4,199 ' DPM. REV/OUT @ 3 BPM 150 PSI,TORQUE=2K @ 60 RPM. REV/OUT BTMS UP PRIOR TO EACH CONNECTION UNTIL RETURNS CLEAN. 02/11/15-Wednesday CONT TO DRILL OUT CEMENT FROM 4,200' DPM TO 4,278' DPM PUMPING 3 BPM, 160-180 PSI, ROTATING 60 RPM,WOB 5- 7K. CIRC BOTTOM UP PRIOR TO EACH CONNECTION OR AS NEEDED. CONT DRILLING MEDIUM TO SOFT CEMENT FROM 4,278'TO 4,300' PUMPING IN REV @ 3 BPM, 200 PSI,TORQUE 2-3K, 60 RPM, 7K WOB, 15-50 FH ROP, MAX GAS 150 UNITS. REV CIRC BTM UP @ 4,300' @ 3 BPM, 200 PSI. CONT DRILLING CEMENT FROM 4,300'TO 4,317' DPM @ 25/50 FPH. RIG UP AND TEST CSG TO 500 PSI FOR 10 MIN @ 4,317'(TEST GOOD). DRILL PLUG @ 4,317' MD 3 BPM, 180 PSI,TORQUE 2-3K @ 60 RPM, 7-8K WOB. LINE UP ON GAS BUSTER DUE TO GAS(200 UNITS TO 1331 UNITS). SECURE WELL DUE TO GAS ALARMS AND REPORT TO MUSTER AREA.OPEN WELL AND MONITOR SAME(STATIC). LINE UP TO PUMP ON TBG AND SEND RETURNS TO WELL CLEAN TANK AND CLEAN SAME. DRAIN OIL FROM RETURN TANK AND CLEAN SAME. ATTTEMPT TO CIRC WELL AND SEND RETURNS TO TRADING BAY. UNABLE TO PUMP. PIPE PLUGGED.ATTEMPT TO REV(SAME). RIG UP MUD BUCKET. BREAK OUT POWER SWIVEL AND SINGLE OF 3.5"TBG. RIG DOWN FOSTER TONGS AND RIG UP MCCOYS DUE TO WORKING HEIGHT OF MUD BUCKET. CHANGE OUT DIES ON MCCOYS. MONITOR WELL DUE TO GAS MIGRATING OUT OF TBG. Hilcorp Alaska LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date D-20 50-733-20203-00 169-095 2/5/15 3/22/15 Daily Operations: 02/12/15-Thursday Service rig and safety compliance check. Cont monitor well. Perform general rig maintenance and house keeping while waiting on E-Line to arrive from OSK. Assist crane crew off load E-Line equipment,spot in place and rig up same. Make up 1-11/16 WT Bar and 1-11/16 CCL on e-line test lubricator to 2500 PSI test good. RIH with E-Line tag @ 4,126' ELM. POOH w/E-Line drain oil from lubricator and make up 1-11/16 tbg punch. RIH w/tbg punch to 4,131'WLM put 500 PSI on tbg attempt to punch holes from 4,132'to 4,135'WLM, no success, POOH. Make up new 1-11/16 tbg punch and RIH w/same to 4,131'WLM put 500 psi on tbg fire punch, pressure bleed off( punch holes @ 4,132'to 4,135'WLM) POOH. Rig down e- line. Had JSA, rig up and circ 1 1/2 well vol 3 BPM, 300 PSI sending return to Trading Bay(total pumped 465 BBLs). Rig down McCoys and stripper head. Off load Weatherford tongs and hydraulic power pack from boat. Rig up Weatherford hydraulic power pack to Foster tongs(due to rig hydraulics being down). POOH w/3.5" PH6 workstring to unplug BHA. 02/13/15-Friday Service rig and perform safety compliance check. Change out mechanical power pack. Rig down Foster tongs and rig up Mccoy power tongs and plumb up same while electrician wires up power pack. Drain BOP stack to production and wash out same due to BOP stack full of oil. POOH with BHA assy top drill collar,cross over,and half of 1st jt of drill pipe plugged with fiber cuttings. Clean out same and inspect bit(ok). Clean rig floor, BOP area and pipe rack area. RIH with 8.5" bit assy to 4,297' DPM. Rig up stripper head and power swivel. Break circ,wash down from 4,297' DPM tag @ 4,317' DPM. Engage power swivel rotating @ 60 RPM pumping 3 BPM torque 2500,WOB 7K-8K break through @ 4,320' DPM. Rev circ well clean from 4,325' DPM pumping 3 BPM. Pumped 337 BBLs total. Line up to pressure test. Test csg 500 PSI for 10 min (good test). RIH with 2 jts of workstring on power swivel. Rig down power swivel and stripper head. RIH with 3.5" PH6 workstring picking up from pipe rack strapping and drifting same to 6,072'. Start rev circ @ 3 BPM, 325 PSI. Started getting gas back,went up to 1000 units.Stop circ and rig up circ hose to well clean tank. Cont rev circ @ 3 BPM,340 PSI sending returns to Trading Bay. (circ 120 BBLS total) Monitor well, static. Cont RIH w/3.5" PH6 workstring picking up from pipe rack to 7,783'. Rig up and start rev circ 120 BBLs @ 3 BPM,345 PSI sending returns to TBAY. 02/14/15-Saturday CONT REV CIRC FROM 7,783' DPM PUMPING 3 BPM 360 PSI, SENDING RETURNS TO TRADING BAY. PUMPED TOTAL OF 215 BBLS. RIG DOWN CIRC HOSE AND BLOW DOWN SURFACE LINES. CONT RIH PICKING UP SINGLES DRIFTING AND STRAP SAME.TAG TOP OF LINER @ 9,467' DPM. RIG UP STRIPPER HEAD AND POWER SWIVEL. BREAK CIRC ENGAGE POWER SWIVEL 20 RPM TAG AND VERIFY LINER TOP @ 9,467' DPM. REV CIRC @ 3 BPM, 510 PSI SENDING RETURNS TO TRADING BAY, PUMPED TOTAL 292 BBLS. TEST CSG TO 500 PSI TEST GOOD. CONT REV CIRC TAKING RETURNS IN RIG TANK PUMPING 3 BPM,420 PSI PUMPED TOTAL OF 770 BBLS TOTAL DUE TO GAS. BLOW DOWN SURFACE LINES AND RIG DOWN POWER SWIVEL AND STRIPPER HEAD. POOH WITH 3.5" PH6 WORKSTRING AND 8.5" BIT ASSY. FINISH POOH WITH 3.5" PH6 WORKSTRING AND 8.5" BIT ASSY TO 4,031' DPM (56K PIPE WEIGHT). MAKE UP RTTS AND STORM VALVE. RIH WITH SAME AND SET @ 200' BELOW MUD LINE, PPH WITH 3.5" WORKSTRING AND STINGER. RIG UP AND TEST RTTS TO 1500 PSI FOR 30 MIN (TEST GOOD). CLEAR RIG FLOOR. REMOVE FLOOR. RIG DOWN POLLUTION PAN. NIPPLE DOWN HCR VALVE AND HOOK ONTO BOP STACK. NIPPLE DOWN WELL HEAD AND INSTALL NEW WELL HEAD. Hilcorp Alaska LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date D-20 50-733-20203-00 169-095 2/5/15 3/22/15 Daily Operations: 02/15/15-Sunday CONT NIPPLE DOWN CIW-DCB 13 5/8"3M X 11 5M TUBING HEAD. PICK UP BOP STACK WITH BLOCK. REMOVE TBG HEAD. INSTALL 13 5/8"3M X 11 5M CACTUSMBS-2 MULTIBOWL WELLHEAD ASSY. LOWER BOP AND NIPPLE UP SAME.ASSIST CAMERON REP TEST VOID 3000 PSI (TEST GOOD)WHILE INSTALLING CHOKE AND KILL LINE ON STACK. INSTALL FLOOR PLATE ALIGN AND SECURE BOP STACK.GATHER TOOLS AND EQUIP FROM WELL BAY.GET RIG IN COMPLIANCE. RIG UP TEST EQUIPMENT. MAKE UP 3.5"TEST JT AND LAND OUT SAME. FILL BOP STACK AND SURFACE LINES. PERFORM SHELL TEST(OK).TEST 11"5M BOPS AND SURFACE EQUIPMENT 250 PSI LOW AND 2500 PSI HIGH ON CHART. TEST BOPS, FLOOR SAFETY VALVES,CHOKE MANIFOLD,CIRC MANIFOLD,STAND PIPE MANIFOLD FOR 3.5"WORKSTRING TO AOGCC AND HILCORP SPECS 250 PSI LOW AND 2500 PSI HIGH. RIG DOWN TEST EQUIPMENT. RIH SCREW INTO RTTS AND STORM PACKER. CLOSE HYDRIL AND TIW. PICKUP AND RELEASE SAME. MONITOR WELL,STATIC. POOH WITH SAME AND LAYDOWN (BREAKING OUT WITH COME ALONG). POOH WITH 3.5"WORKSTRING AND 8.5" BIT BHA. MR. BOB NOBLE, AOGCC WAIVED THE WITNESS BY PHONE CALL AT 10: 09AM ON 2/15/15. RECEIVED EMAIL FROM MR.JIM REGG CONFIRMING WITNESS WAIVED AT 8: 12PM ON 2/15/15. 02/16/15-Monday Service rig and perform safety and compliance check. Break down 8.5" bit assy. Pick up landing jt, remove test plug make up wear bushing and install in well head. Rig up circ hoses to production and install mat on rig floor. Make up 8.5"tandem string mill assy. TIH w/3.5" PH6 work string and tandem mill assy, 75 FPM. Rig down weatherford hyd power pack Install new soft start on rig hydraulics and get back on rig hydraulics. Cont TIH w/3.5" PH6 workstring and mill assy tag at 4,281' DPM.Attempt to work through (no success). Rig up stripper head and power swivel. Break circ engage power swivel, RPM 60, pumping 3 BPM, 250 PSI,Torque 2-3K.Attempt to work through tight spot w/3-5K WOB. Cont milling on tight spot @ 4,281' DPM,3 BPM, 245 PSI, 70 RPM, 2-3K torque,5K WOB(unable to work through tight spot). Rev circ one tbg vol 3 BPM, 245 PSI. Rig down power swivel and stripper head. POOH w/3.5" PH6 workstring and 8.5"tandem mill BHA, lay down same. Make up 8.5"tapered mill, bit sub,drill collar,xover,8.5"string mill,xover, bumper and oil jars,4 drill collars, xover BHA. TIH,w/3.5" PH6 workstring and mill assy,85 FPM,tag tight spot @ 4,281' DPM,fell through with 5K WOB, 2K to pull back through tight spot. Rig up stripper head and power swivel. Start reaming through tight spot @ 4,281' DPM. 02/17/15-Tuesday Service rig and perform safety compliance check. Made connection w/power swivel.Cont RIH from 4,306'to 4,337' DPM. Made connection w/power swivel.Cont RIH f/4,337'to 4,368' DPM. Rig down power swivel and stripper head. Lay down 2 singles. Cont RIH w/3.5 PH6 workstring form 4,368' DPM tag @ 9,222' DPM.Attempt to work through tight spots, no success. Rig up power swivel and stripper head. Cont washing and reaming from 9,222' DPM to 9,467' DPM. Cont clean out tight spots. Pump 3 BPM,400 PSI,Torque 4-5K, WOB 4K, RPM 60.Tag top of liner @ 9,467' DPM. Pick up 10'off of liner top, circ 2 tbg vol until well clean. Finish circ until returns clean. Rig down power swivel and stripper head. POOH w/3.5 PH6 workstring. POOH w/8.5 tapered mill BHA and laydown same. Rig up E-Line,test shoot nipple to 500 PSI (good).Start RIH w/2.75" multi finger caliper. Hilcorp Alaska LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date D-20 50-733-20203-00 169-095 2/5/15 3/22/15 Daily Operations: I ' 02/18/15-Wednesday cJ,: i z (i RIH w/2.75" OD multi finger caliper imaging tool on a-line to 9,458' ELM. Perform csg log from 9,458' ELM to surface. Rig down e-line and shoot nipple. Make up 8.5 tapered mill/bit sub/drill collar/xover/2 tandem string mills/xover/ bumper and oil jars/4 drill collars/xover. Rig down McCoy power tongs and rig up Foster tongs. TIH w/3.5" PH6 workstring and tapered mill assy 75 FPM. Cont TIH w/3.5" PH6 workstring @ 75 FPM found tight spot @ 4,329' DPM set down 1-2K pipe fell through. Rig up stripper head and power swivel. Ream through tight spot several times 3 BPM, 250 PSI, 2-4K torque. Shut down pump and power swivel and work through tight spot several times(ok). Rig down power swivel and stripper head. Cont TIH w/3.5" PH6 workstring 8.5"tapered mill BHA @ 75 FPM tag @ 9,124' DPM. Lay down 12 jts of 3.5"workstring. 02/19/15-Thursday Service rig and perform safety and compliance check. POOH laying down 6 stands to wash with. Run last 6 stands from derrick in the hole. Rig up power swivel and stripper head. Tighten up hydraulic connections on power swivel service loop. Pick up singles with power swivel reaming out tight spots @ 9,114'-9,116' DPM,9,370'-9,375' DPM, pumping 3 BPM 1-3K WOB,Torque 3-5K Tag TOL @ 9,467' DPM. Circ bottom up @ 3 BPM 350 PSI returns clean. Rig down power swivel and stripper head. POOH with 3.5" PH6 work string and BHA. Lay down 8.5"tapered mill and string mills BHA. Make up 6" rock bit/bit sub/bumper jars/oil jars/4 drill collars. Start TIH w/3.5" PH6 workstring tag tight spot @ 4,282' DPM w/5K WOB rotate pipe 2K,fell through,cont TIH to 9,452' DPM. Rig up stripper head and power swivel. Break circ in rev and tag @ 9,468' DPM start milling 3 BPM,390 PSI, 70 RPM,4-6K torque,4K WOB broke through @ 9,472' DPM wash and ream down to 9,483' DPM. Shut down and rig up circ hoses to production to send returns to TBAY. 02/20/15-Friday REV CIRC FROM 9,462'dpm PUMPING 2 bpm, 175 PSI SENDING RETURNS TO TBAY,TOTAL 2 TBG VOL, 140 BBL. SHUT DOWN PUMP. LINE UP TO TAKE REUTNRS IN RIG TANKS. RIH TO 9,499'dpm CIRC 1 TBG VOL, 70 BBLS PUMPING 3 BPM 400 PSI TILL RETURNS ARE CLEAN. RIG DOWN POWER SWIVEL AND STRIPPER HEAD. POOH W/3.5" PH6 WORKSTRING. LAY DOWN 6" BIT BHA. MAKE UP 7.38" POLISH BORE MILL/PUP JT/TOP DRESS OFF MILL/XOVER/BUMPER AND OIL JARS/ 4 DRILL COLLARS/XOVER. RIH W/7.38" POLISH MILL ASSY 75 FPM. PICK UP POWER SWIVEL AND BREAK OFF XOVERS AND TIW TO SEND TO GRAYLING. CONT RIH WI 7.38" OD POLISH MILL ASSY ON 3.5 PH6 WORK STRING, 75 FRPM TO 9,461' DPM. LAY DOWN TOP SINGLE ON STAND#150. RIG UP STRIPPER HEAD AND POWER SWIVEL. DRESS OF TOP OF LINER @ 9,467' DPM AND CONT POLISHING DOWN TO 9,474'dpm. WORK THROUGH SEVERAL TIMES @ 3BPM, 345 PSI, 60 RPM. REV CIRC UNTIL RETURNS CLEAN UP WITH NO SOLIDS. CLEAN MUD TANKS TO PREPARE TO PUMP WELL FLUSH. 36 BBLS OF FIW IN SHAKER PIT#2 AND ADD 2 DRUMS OF BARAKLEAN. 02/21/15-Saturday Rig up circ hoses to production header. Flush out surface lines.Clean return pit. Pump 30 BBL caustic and baraklean and disp well with 8.5 FIW sending all returns to TBAY, pumping 3 BPM,540 PSI pumped total of 1600 BBLs. MR JIM REGG WITH AOGCC WAIVED WITNESS @ 5:58PM ON 2/21/2015. Finish pumping to TBAY @ 3BPM 540 PSI total sent 1654 PSI. Weight up mud to 9.6 PPG. Circ well vol mixing salt on the run (when all returns came back around had 9.3 PPG coming back) pumping @ 2 BPM 180 PSI. Cont circ another well vol maintaining a 9.6 PPG going in pumping @ 2.5 BPM, 200 PSI. Hilcorp Alaska LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date D-20 50-733-20203-00 169-095 2/5/15 3/22/15 Daily Operations: 02/22/15-Sunday Continue circulating 9.6 ppg Cad!surface to surface pumping 2 bpm 300 psi Total 675 bbls. Rig down circulating equipment and blow down surface lines. POOH w/3.5" PH6 Workstring. Lay down polish mill assembly.Secure well, remove 2-7/8"x 5"VBR from BOP and install 7-5/8"Casing Rams(Serial#K1626). Pull wear bushing, make up 7-5/8"test assembly. Test 11"5M BOPs and surface equipment as per AOGCC&Hilcorp Specs. 250L/2500H. Witness waived by Mr. Jim Regg AOGCC. Rig Down Test equipment. Slip and cut 70'drill line. Retest Crown-O-matic. Clear rig floor, rig down Foster tongs& BJ tongs. Rig Up Weatherford slips and pipe handling equipment. M/U 7-5/8" Mule Shoe w/double float collars&start TIH_w/7-5/8" casing picking up from pipe rack strapping&drifting same. 02/23/15-Monday CONT RIH W/7-5/8" FLOAT ASSY AND 7-5/8 CST,STRAP AND DRIFT. ASSIST WEATHERFORD WITH MAKING UP CONNECTIONS. WELL U-TUBING, BUILD SURFACE VOL TO 9.6 PPG. CIRC LONG WAY @ 2 BPM, 20 PSI TAKING RETURNS IN RIG TANK. PUMPED TOTAL OF 153 BBLS. CONT RIH WI FLOAT ASSY AND 7-5/8 CSG. CONT RIH W/7-5/8 CSG.WORK THROUGH TIGHT SPOT AT 4,282'. CONT RIH TO 5,854'. OFF LOAD REMAINING CSG FORM WORK BOAT AND LAY OUT ON PIPE RACK. CONT RIH WITH 7-5/8 CSG STRAPPING AND DRIFTING SAME. CURRENT DEPTH 7,342'. 7-5/8"CSG, 29.7#, L-80, SLIJ-II CSG. 02/24/15-Tuesday CONT RIH/7-5/8 FLOAT ASSY AND 7-5/8 CSG, STRAP AND DRIFT. MAKE UP CONNECTIONS. CONT RIH WI 7-5/8 CSG, 233 JTS TAG @ 26FT IN JT 234. PU 165K,SO 115K, WEIGHT 29.7 PPF,GRADE L-80,TORQUE 11K.SAT DOWN 5K ON TOP OF LINER. LAY DOWN 2 SINGLES. SPACE OUT LAND HANGER.VERIFIED HANGER LANDED IN WELL HEAD. RIG DOWN WEATHERFORD POWER TONGS AND PHE.ASSIST CRANE CREW MOVE MISC EQUIP AND OFFLOAD HALLIBURTON CEMENT. SPOT AND LAND ON PIPE RACKS. RIG UP CIR HOSES FROM WELL HEAD TO RETURN PIT. RIG UP AND FILL 7-5/8 CSG WITH 8.5 PPG FIW, CONT PUMPING DISPLACING 9.6 PPG SALT WATER AND CONT CIRC UNTIL RETURNS CLEAN. RIG UP HOSES AND HALLIBURTON CEMENT. RIG UP CEMENT HEAD AND HIGH PRESSURE LINES. RIG UP PROD TO BE ABLE TO SUPPLY 6 BPM FIW TO CEMENT UNIT. CLEAN AND SERVICE RIG WHILE WAITING ON TOWER CHANGE TO PERFORM CEMENT JOB. Hilcorp Alaska LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date D-20 50-733-20203-00 169-095 2/5/15 3/22/15 Daily Operations: 02/25/15-Wednesday HELD PREJOB MEETING. PRIME PUMP AND TEST LINES TO 5000 PSI (OK). PUMP 10 BBLS FIW SPACER. DROPPED BTM PLUG. MIX AND PUMP 414 SACKS CLASS"G"CMT, 177 BBO SLURRY MIX @ 12.5 PPG W/2.41 YIELD WI 13.5/SX MIX WATER PUMPED @ 4 BPM FOLLOWED W/104 SX CLASS"G"CMT 21.6 BBL SLURRY MIXED @ 15.8 PPG W/1.17 YIELD WL ,1,;- 5.10 G/SX MIX WATER PUMP @ 3 BPM. DROP TOP PLUG DISPLACE W/8.5 PPG FIW @ 6 BPM. FINAL CIRC PRESSURE 3750 t-' . PSI @ 2 BPM. BUMPED PLUG WI 500 PSI OVER @ 4250 PSI.TOTAL BBLS PUMPED 411.6/CALCULATED 433 BBLS. HELD PRESSURE 5 MINUTES BLEED OFF SAME W/5 BBL BACK. FLOATS HELD OK. HAD 100%FULL RETURNS BACK DURING JOB_, CEMENT IN PLACE @ 1045 am. NO CEMENT BACK IN RETURNS. RIG UP AND FLUSH STACK AND WELL HEAD HAD CLEAN WATER BACK IN RETURNS. RIG DOWN CEMENT EQUIPMENT AND LINES. MONITOR WELL AND RIG DOWN CIRC EQUIP FROM WELL BAY. MAKE UP 3.5" PH6 LANDING JT ASSIST CAMERON REP SET PACK OFF IN MULTIBOWL WELL HEAD ASSY. FINISH ASSIST CAMERON REP SET PACK OFF IN MULTIBOWL WELL HEAD ASSY. RUN IN LOCK DOWN PINS AND TEST VOID 5000 PSI (OK). PULL PACK OFF RUNNING TOOL. OFF LOAD AND SPOT HALLIBURTON E-LINE EQUIPMENT. RIG UP SHOOT NIPPLE FLANGE WHILE E-LINE RIGGED UP AND CHECKED EQUIPMENT. HELD PRE JOB SAFETY W/RIG CREW AND HALLIBURTON. RIG UP SHEAVE AND SHOOT NIPPLE. HALLIBURTON MAKE UP TOOL STRING. TEST SHOOT NIPPLE 1500 PSI (OK). RIH WI 1-11/16"TEMP LOG TOOL TAG @ 8,500'WLM. POOH LOGGING TO SURFACE LAY OUT SAME. MAKE UP 2.75" CEMENT BOND LOG AND RIH WITH SAME CALIBRATE TOOL AND CONT RIH TO 8,500'WLM. POOH PERFORMING BOND LOG. 02/26/15-Thursday CONT POOH WI 2.75 CEMENT BOND LOG @ 50 FPM. RIG DOWN HALLIBURTON E-LINE. SECURE WELL. CHANGE RAMS FROM 7-5/8"CSG RAMS TO 2-7/8"X 5"VBRs. CLEAR AND CLEAN WORK AREA AND RIG UP FOSTER TONGS. RIG UP 3.5" TEST EQUIPMENT. LAND TEST JT. TEST 11"5M BOPs AND SURFACE EQUIPMENT AS PER AOGCC AND HILCORP SPECS TO 250 PSI LOW/2500 PSI HI. BOP TEST WITNESS WAIVED BY MR.JIM REGG WI AOGCC ON 2/24/15 @ 19: 10pm. PERFORM KOOMEY TEST(OK). RIG DOWN TEST EQUIPMENT. INSTALL WEAR BUSHING IN WELLHEAD. CLEAR RIG FLOOR. PULL FLOOR PLATE. RIG DOWN POLLUTION PAN. NIPPLE DOWN RISERS FROM TOP OF HYDRIL. MAKE UP 2.5' RISER, 2' RISER WITH 6"AND 2" OUTLETS INSTALLED IN SAME AND 1' RISER SPOOL INSTALL ON TOP OF HYDRIL. RIG BACK UP POLLUTION PAN AND FLOOR PLATE. MAKE UP 6-3/4" ROCK BIT, BIT SUB,OIL AND BUMPER JARS,4 DRILL COLLARS AND XOVER BHA TOTAL OVERALL LENGTH OF BHA 146.94'. TIH WITH 3.5" PH6 WORKSTRING TO 8,235' DPM. RIG UP 6" FLOW LINE FROM TOP OF BOPS TO SHAKER. RIG UP 2" HOSE TO TOP OF BOPs. CONT RIH WITH 3.5" PH6 WORKSTRING TAGGING UP @ 8,545' DPM. RIG UP AND REV CIRC 2 TBG VOL. CEMENT RETURNS BACK ON FIRST TBG VOL. REDUCED PUMP RATE, CONT REV CIRC GREEN CEMENT UNTIL RETURNS CLEANED UP, PUMPING @ 3 BPM 380 PSI. 02/27/15-Friday Cont Rev Circ @ 3 BPM 380 PSI Pumped Total 63 BBLS. Broke Circulation Long Way Test 7 5/8" 29#L-80 CSG To 2500 PSI On Chart For 30 Min. @ 14 SPM 81 STK 3 BBLS. Rig up Stripper Head & Power Swivel. Line Up On PZ9&Circ Thru Surface Lines& Flow Line. Found A Leak On Flow Line. Repair Same. Wash Down f/8,547' Pumping 7 BPM 1626 PSI No WOB.Tag & Drill Plug F/ 8,575 To 8,578',Torque 5-6K W/1625 PSI, Cont Drlg Soft Cmt F/8,578'To 8,672' Pumping @ 8 BPM WOB 0- 2K 1975 PSI. PH IN Active System @ 18:00 7.1. Cont Drlg Soft Cmt F/8,672'To 8,984' Pumping @ 7-8 BPM -WOB 0-2K, Torque 5-6K. Check PH In Active System @ 8,829' 11.5 Started Adding Citric Acid To Active System @ 8,922'.Check PH In Active System PH 12.1 Increase Treatment To Active System. 7 total sacks of citric acid added. Hilcorp Alaska LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date D-20 50-733-20203-00 169-095 2/5/15 3/22/15 Daily Operations: 02/28/15-Saturday CONT DRILLING AND WASHING CEMENT FROM 8,984'..-.9,205'DPM @ 8 BPM, ICP=1690 PSI,TORQUE 5300-5500,WOB 1K, RPM 80, FCP 2130 PSI. ROP 100' FPH CIRC BOTTOMS UP PRIOR TO EA CONNECTION. 9,205' DPM TAGGED UP HARD CEMENT WOB 3-5K, RPM 80 @ 8 BPM, 2103 PSI, ROP 100 FPH,CIRC BOTTOM UP PRIOR TO EA CONNECTION.DEPTH @ 1800 9,237' DPM. CONT DRILLING OUT CEMENT FROM 9,237' DPM 7-8 BPM, 1700 PSI,80 RPM, 3-5K WOB,TORQUE 5-6K, 100 FPH,TAG WIPERPLUG_@ 9,461'DPM. CIRC BOTTOMS UP 7-8 BPM, 1800 PSI AND RIG UP TEST CHART TO TEST CASING TO 2500 PSI ON CHART FOR 30 MINUTES. h\<< 03/01/15-Sunday Rig up equip. broke circulation long way&through kill line. Pressure test 7 5/8" 29#L-80 SLIJ-II csg on chart for 30 min.to 2500 psi.Test good 15 spm 3.4 bbls. Rig down circulation hose& rig up power swivel. Broke circulation W/pump 5 spm 960 psi. Circulate well while reposition flow line on gas buster. Line up on pz9 pump. Broke circulation tag 7 5/8"cmt. plug @ 9,461' DPM. Engage power swivel pumping @ 8 bpm 2280 psi,WOB 2-3 K,torque 55-6 K. Drilled plug& 2-float collars final depth 9,468' DPM.. Circulate hole clean @ 9,468' pumping @ 8 bpm WI 1975 PSI. Rig down power swivel& stripper head. POOH WI 6.75 bit, BHA&3.5 PH6 workstring to 8,080'secure well. Assist welder install rack under catwalk for 6"flow line. Install flow line in rack under catwalk& installing Quado flow show. Started POOH WI 3.5 PH6 working string. (Fluid not dropping in workstring). Rig up stripper head &broke circulation test flow show&calibrate same. Close pipe ram &reverse circulate 1-tubing volume. Open pipe rams& rig down stripper rubber. Finish POOH W/3.5 PH6 workstring, BHA& laid out 6.75 bit. Responded to Rig Alarm,went to muster area and waited for all clear from production, Made up 6" rock bit,TIH WI BHA&3.5 PH6 workstring. 03/02/15-Monday Service rig&perform safety&compliance check. Continue TIH W/6" bit, BHA&3.5#PH6 workstring to 9,452' DPM. Rig up stripper head & power swivel. Broke circulation. Wash down F/9,452'to 9,553',80 rpm,8 bbls min. 2350 psi,torque 5500, WOB-0, rotating P/U wt. 105K, S/O wt. 105K.Tag @ 9,553". Circulate bottom up max gas 515 units. Getting backsand across shakers. Bit bouncing while rotating @ 9,553'. Circulate well clean @ 9,505' pumping 8 BPM 2200 psi. Rig down power swivel. Blow surface line down & prepare to clean mud tanks. HPJSM.Clean out rig putting all cutting in cutting boxes. Rig up reverse lines to production&reverse circulating well volume @ 9,552'sending returns to Trading Bay @ 3 BPM 430 psi. 03/03/15-Tuesday CONT REV CIRC TO PROD WELL CLEAN PUMPING 3 BPM 310 PSI 555 BBLS TOTAL. LINE UP PZ9 CONT CIRC @ 8 BPM 2281 PSI,GAS 104, PUMPED TOTAL OF 228 BBLS. LINER PLATE ON PZ9 LOOSE. SHUT DOWN PUMP. CONT CIRC W/PAH PUMP 5 BPM, 1980 PSI, GAS 105, 194 BBLS WHILE REPAIRING PZ9. CONT CIRC W/PZ9 @ 8 BPM, 2128 PSI, 206 BBLS. MONITOR WELL(WELL STATIC). CIRC BOTTOM UP @ 8 BPM 2264 PSI. MONITOR WELL. WEIGHT UP SURFACE VOL TO 8.8 PPG CACL. PUMP 8.8 PPG CACL @ 5 BPM, 770 PSI, 394 BBLS. RIG DOWN CIRC EQUIP. LAY OUT SINGLE. RIG DOWN STRIPPER HEAD AND BLOW DOWN SURFACE LINES. POOH W/3.5 PH6 WORKSTRING AND 6" BIT ASSY. FINISH POOH W/3.5 PH6 WORKSTRING AND 6" BHA. MAKE UP 5.75 OVERSHOT BHA W/2-5/8" GRAPPLE. TIH WITH 3.5" PH6 WORKSTRING TO 9,548' DPM. RIG UP STRIPPER HEAD. INSTALL TIW AND SPACE OUT WITH PUP JT. Hilcorp Alaska LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date D-20 50-733-20203-00 169-095 2/5/15 3/22/15 Daily Operations: 03/04/15-Wednesday Continue rev. out W/8.8 ppg FIW @ 3 bpm 450 psi,total pumped 80 bbls. Set down 10K on pkr plug. P/U to 132K(6K above normal drag)allow fluid to equalize. POOH to 9,532'dpm. Rev. circulate @ 2 bpm 300 psi,fluid returns clean.Total 8.8 ppg FIW pumped 160 bbls. R/D circulating hoses. N/D&remove stripper head. POOH slow W/3 1/2" ph6, pkr plug, overshot& BHA. Broke down BHA. No packer plug. Broke down overshot&inspect same. No indication overshot was over the pkr plug. Wash&clean floor. N/D bell nipple&remove same. N/U riser from Hydril to rig floor. Finish N/U riser to rig floor. Install floor plates&secure pollution pan around stack. M/U 5.750" burning shoe, 5.750 washpipe ext. W/flapper valve,(2)jts 5.75"washpipe, oil jars&(4)4.750"drill collars. (Total length of BHA -217.22'). TIH W/5.750" burning shoe BHA&3 1/2" PH6 to 9,522' DPM. N/U stripper head. N/U&P/U power swivel. Reverse out 1 tbg vol at 2 bpm, 315 psi. Make connection and wash and ream f/9,553'to 9,554'.with 6 to 7k torque,w/70 rpm pumping 2.5 bpm 315 psi in reverse. AOGCC, Mr.Jim Regg requested an extension on the BOP test to facilitate a witnessed test on Friday March 6th, 2015 by email response on March 3rd, 2015 @ 15: 37 PM. 03/05/15-Thursday CONT WASH AND ROTATE DOWN FROM 9,554'-9,605' DPM, PUMPING 2-1/2 BPM 315 PSI, RPM=60.TORQUE=6K,WOB=1- 2K. REV/OUT @ 3-1/2 BPM 560 PSI UNTIL RETURNS CLEAN. RECOVERED GRAVEL PACK SAND AND DEBRIS AT BTMS UP. TOTAL PUMPED=180 BBLS. R/D& L/D POWER SWIVEL. N/D STRIPPER HEAD AND INSTALL WIPER RUBBER. POOH W/3- 1/2" PH6 AND BURNING SHOE ASSY BHA. B/D AND L/D BURNING SHOE BHA. WASH/CLEAN RIG FLOOR AND PREP SAME TO TIH. M/U 5.75"0/5 DRESSED W/2.75"GRAPPLE, OIL/BUMPER JARS&(4)4-3/4" DRILL COLLARS. BHA#11 = 148.00'. TIH W/3-1/2" PH6 AND OVERSHOT BHA. R/U CIRCULATING HEAD SLACKED OFF AND TAG FISH @ 9,605'. P/U AND HAD OVER PULL 6K,SLACKED OFF AND SET 10K DOWN. PICKED BACK UP AND HAD NO OVER PULL. REV CIR 2 TUBING VOLUMES. MONITOR WELL FOR LOSSES(WELL TAKING 1-1/4 BBL PER HR). R/D CIRCULATING HEAD AND PREP TO POOH. POOH WITH OVER BHA#11( 5-3/4"OVERSHOT ASSY). 03/06/15-Friday CONT. POOH W/3-1/2" PH6 AND OVERSHOT BHA. RTY 5 3/4" KOT SHOE, 5 3/4"WASH PIPE EXT. 3 1/2" IF X 5 3/4" KOT TOP BUSHING, BUMPER JARS 3 1/2"IF, OIL JARS 3 1/2" IF,4-DC 3 1/2" IF, 3 1/2 PH6 X 3 1/2" IF XO SUB. =157.08'. B/D OVERSHOT ASSY BHA. DID NOT RETRIEVE PACKER PLUG. PULL WEARBUSHING. R/U TEST JT AND LAND TEST PLUG. R/U TEST EQUIPMENT. TEST 11"X 5M BOPS AND SURFACE EQUIPMENT AS PER AOGCC& HILCORP SPECS, 250 LOW/2500 HIGH ON CHART DATED 3-6-2015.TEST FROM MAIN & FUNCTION REMOTE.TEST WITNESSED BY JOHN CRISP AOGCC REP. PULL TEST PLUG. INSTALL WEARBUSHING AND RIG DOWN TEST EQUIPMENT. N/D RISER FROM TOP OF HYDRIL. N/U FLOW CROSS AND RIG UP FLOW LINE. FINISH REMOVING RISER SPOOL AND N/U FLOW CROSS FOR FLOW LINE. M/U BHA#12---- 5.750 BURNING SHOE,5.750 WASH PIPE EXTENSION, OIL/BUMPER JARS&(4)4-3/4" DRILL COLLARS.TOTAL LENGTH = 157.08'. TIH W/3-1/2" PH6 AND BURNING SHOE BHA TO 9,587'. N/U STRIPPER HEAD. P/U AND R/U POWER SWIVEL. SLACKED OFF AND TAGGED AT 9,605.50'. ROTATED PIPE AND SLACKED OFF TO 9,608'STARTED MILLING WITH 1-2k WT DOWN, 80 RPM,6-7K TORQUE. Hilcorp Alaska LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date D-20 50-733-20203-00 169-095 2/5/15 3/22/15 Daily Operations: 03/07/15-Saturday CONT BURNING OVER PKR F/9,608'-9,609' DPM, PUMPING 8 BPM 2150 PSI, 70 RPM,TORQUE=5-6K.WOB=3-5K. MIX AND PUMP 5 BBL HI-VIS SWEEP. CONT MILLING OVER PKR AT 9,609' DPM, NO SUCCESS GETTING DEEPER, PUMPED 10 BBL SWEEP GETTING SCALE AND FINE METAL BACK IN RETURNS. ATTEMPT TO DRY DRILL ON PKR NO SUCCESS. PIPE TORQING UP AND STICKING. HITTING JARS AT 170K. (40K OVER) PIPE FREE. LINE UP PUMP TO REV/OUT, PUMPING 3 BPM 300 PSI, PIPE STICKING, HITTING JARS AT 170K(40K OVER)TO FREE PIPE. PUMP 10 BBL HI-VIS SWEEP DOWN BACKSIDE TO BIT. LINE UP TO CIRCULATE DOWN TBG. PUMP DOWN TBG @ 10 BPM 2600 PSI.WORK PIPE FREE HITTING JARS @170K(40K OVER) PIPE FREE. POOH W/POWER SWIVEL LAYING DOWN SINGLES UNTIL NO MORE DRAG.TOTAL JTS LAID DOWN=6.APPROX. 189' PIPE FREE. POOH WITH BURNING SHOE ASSY AND L/O SAME. SHOE 100%WORN. SLIP AND CUT 95' DRILL LINE. RECALIBRATE HMI. RE-SET C-O-M AND CHECK W/DRILL LINE "OK". WASH/CLEAN RIG FLOOR AND CHANGE OUT HYD TONGS. M/U BHA#13 6" BURNING SHOE OIL AND BUMPER JARS,4-3/4 DRILL COLLARS. TOTAL BHA LENGTH = 156.08'. 03/08/15-Sunday SERVICE RIG AND SAFETY COMPLIANCE CHECK. FINSH M/U BURNING SHOE BHA. TIH W/3-1/2" PH6 AND BURNING SHOE BHA TO 9,461' DPM. N/U STRIPPER HEAD AND RIG UP POWER SWIVEL. MAKE CONNECTION & INSTALL STRIPPER RUBBER. EST. DRILLING PARAMETERS, PUMPING 3 BPM 500 PSI. BPM=70,TORQUE=5-6K.ALL PUMPING DONE IN REVERSE. WASH DOWN F/9,461'-9,609' DPM.TAG TOF @ 9,609' DPM, REV/OUT 1 TBG VOL EVERY CONNECTION. BURN OVER PKR FROM F/9,609'TO 9,611' DPM. PUMPING 3 BPM,300 PSI, RPM=70,TORQUE=6-7K,WOB=2-4K.ALL PUMPING DONE IN REVERSE. GETTING BACK 75%OIL IN RETURNS. LINE UP TO PUMP DOWN TBG, DISPLACE WELL W/#8.8 F.I.W. @ 3 BPM 1450 PSI, TOTAL PUMPED=550 BBLS. DRAIN MUD TANKS TO TRADING BAY.WASH AND CEAN OIL FROM MUD TANKS. 03/09/15-Monday CONT WASH AND CLEAN MUD TANKS. CONT BURNING OVER PKR F/9,611' DPM, PUMPING @3 BPM 350 PSI, RPM=70, TORQUE=6-7K,WOB=2-4K.ALL PUMPING DONE IN REVERSE,"PKR FREE", PUSH SAME DOWN HOLE TO 9,618' DPM. REV/OUT @ 3 BPM 350 PSI UNTIL RETURNS CLEAN.TOTAL PUMPED=220 BBLS. RIG DOWN AND LAY DOWN POWER SWIVEL. N/D AND REMOVE STRIPPER HEAD. POOH W/3-1/2" PH6 AND BURNING SHOE BHA. CONT. POOH W/3-1/2" PH6 AND BURNING SHOE BHA. BREAKDOWN AND LAYDOWN BHA. FOUND TOP HALF OF BAKER SB PLUG HUNG INSIDE BURNING SHOE. M/U 5.75"OVER SHOT DRESSED W/4.625"GRAPPLE,OIL/BUMPER JARS&(4)4-3/4" DC'S.TIH W/3-1/2" PH6 AND OVERSHOT BHA,TAG AT 9,610' DPM. P/U SINGLES OUT OF V-DOOR AND CONT TIH,TAG PKR AT 9,630' DPM. PUSH DOWN HOLE TO 9,687' DPM.SET DOWN (30K)AND LATCH SAME. P/U TO 130K(11K)OVER. INDICATION PACKER LATCHED. POOH SLOW W/3-1/2" PH6& OVERSHOT ASSY. Hilcorp Alaska LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date D-20 50-733-20203-00 169-095 2/5/15 3/22/15 Daily Operations: 03/10/15-Tuesday SERVICE RIG AND SAFETY COMPLIANCE CHECK. CONT POOH W/3-1/2" PH6, BURNING SHOE BHA& FISH. B/D BHA, "NO FISH", BREAK DOWN OVER SHOT&INSPECT GRAPPLE. NO INDICATION OF FISH ON GRAPPLE. INDICATION OF JUNK ON OUTSIDE OF GUIDE. M/U 6"JUNK MILL, OIL/BUMPER JARS&(4)4-3/4" DC'S,TOTAL LENGHT OF BHA 15= 147.70'. TIH W/3-1/2" PH6 AND MILLING ASSY BHA. SERVICE RIG AND SAFETY COMPLIANCE CHECK. CONT.TIH W/3-1/2" PH6 AND MILLING ASSY BHA TO 9,440' DPM. M/U KELLY JT& REVERSE WASH THRU LINER TOP TO 9,471' DPM, PUMPING 3 BPM 250 PSI,TOTAL PUMPED-27 BBLS. CONT.TIH W/3-1/2" PH6 AND MILLING ASSY BHA TAG @ 9,687' DPM. N/U STRIPPER HEAD. P/U & R/U POWER SWIVEL. MAKE CONNECTION AND ESTABLISH DRILLING PARAMETERS. PUMPING 3 BPM 350 PSI, TORQ=6-7K, RPM=70, P/U=128,S/0=92. MILL&WASH DOWN F/9,687'-9,697' DPM . PIPE PLUGGING, LINE UP LONG WAY & UNPLUG PIPE AS NEEDED. PIPE PLUGGED. LINE UP LONG WAY& UNPLUG PIPE. PUMPING AT 3 BPM 350 PSI (INITIAL PRESS=1500 PSI).TOTAL PUMPED=120 BBLS. CONT MILLING F/9,697' DPM. PUMPING 3 BPM 350 PSI,WOB=5- 11K,TORQ=6-7K, RPM=75,ALL PUMPING DONE IN REVERSE. UNABLE TO MILL DEEPER. REVERSE BOTTOMS UP BEFORE POOH.WHILE MILLING GETTING PARAFFIN, SCALE AND METAL BACK IN RETURNS. 03/11/15-Wednesday CONT REV/OUT @ 3BPM 350 PSI UNTIL RETURNS CLEAN.TOTAL PUMPED=250 BBLS. L/D POWER SWIVEL AND N/D STRPPER HEAD. POOH W/3-1/2" PH6 AND MILLING ASSY BHA. B/D BHA AND INSPECT MILL. MILL ABOUT 40%WORN, OUTSIDE EDGES ROUNDED OFF. HYD HOSE BUSTED. C/O HOSE AND INSTALL FITTINGS ON SAME. M/U 5.50"JUNK MILL, 2- JUNK BASKETS,OIL/BUMPER JARS&(4)4-3/4" DC'S. 159.96'. TIH W/3-1/2" PH6 AND MILLING ASSY BHA. SERVICE RIG AND SAFETY COMPLIANCE CHECK. CONT.TIH W/3-1/2" PH6 AND MILLING ASSY BHA TO 9,687' DPM. N/U STRIPPER HEAD. P/U AND R/U POWER SWIVEL. MADE CONNECTION. INSTALL STRIPPER RUBBER AND ESTABLISH DRILLING PARAMETERS, PUMPING 3 BPM 400 PSI, RPM=75,TORQUE=6-7K. CONT TIH,TAG FISH @ 9,694' DPM. MILL DOWN TO 9,699' DPM, PUMPING 3 BPM 400 PSI,TORQ=6-7K, RPM=75,WOB=1-9K.ALL PUMPING DONE IN REVERSE. PIPE PLUGGED. ATTEMPT TO UNPLUG PIPE.TRYING TO BREAK CIRCULATION IN REV AND LONG WAY"NO SUCCESS". PRESSURE UP TO 1500 PSI ON BACKSIDE AND 2500 ON TBG. BLOW DOWN CIRCULATING LINES. R/D POWER SWIVEL. N/D STRIPPER HEAD AND RIG UP MUD BUCKET. POOH SLOW W/3-1/2" PH6 AND MILLING ASSY BHA, USING MUD BUCKET DUE TO PIPE BEING PLUGGED. TOTAL METAL BACK=45 LBS. Hilcorp Alaska LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date D-20 50-733-20203-00 169-095 2/5/15 3/22/15 Daily Operations: 03/12/15-Thursday SERVICE RIG AND SAFETY COMPLIANCE CHECK. CONT POOH SLOW W/3-1/2 PH6& MILLING ASSY BHA USING MUD BUCKET. PIPE PLUGGED @ COLLARS. R/D MUD BUCKET AND C/O ELEVATORS. L/D DRILL COLLARS AND MILL ASSY BHA IN V-DOOR,WASHING AND CLEANING OUT EACH JOINT. "NO SUCCESS"WATER FLOOD IN PROD. FROZE UP. LAYOUT(4) DRILL COLLARS&OIL/BUMPER JARS ON PIPE RACK. M/U 5.50" MILL, OIL/BUMPER JARS, (2) BOOT BASKETS& (4)4-3/4" DRILL COLLARS. 162.02'. TIH W/3-1/2" PH6 AND MILLING ASSY, RABITTING PIPE OUT OF DERRICK. SERVICE RIG AND SAFETY COMPLIANCE CHECK. CONT.TIH W/3-1/2" PH6 AND MILLING ASSY, RABITTING PIPE OUT OF DERRICK TO 9,499' DPM. R/U KELLY HOSE AND EST CIRCULATING RATES THE LONG WAY WITH PZ9 PUMPING 8 BPM 1640 PSI. CONT.TIH W/3-1/2" PH6 AND MILLING ASSY, RABITTING PIPE OUT OF DERRICK TO 9,686' DPM. N/U STRIPPER HEAD. P/U & R/U POWER SWIVEL. MAKE CONNECTION. INSTALL STRIPPER RUBBER AND EST. DRILLING PARAMETERS. PUMPING 8 BPM 1650 PSI, RPM=75,TORQ=6-7K. PUMP 5 BBL SWEEP LONGWAY @ 9 BPM 2855 PSI AND DISPL 1 HOLE VOL W/8.8#F.I.W. CONT TIH &TAG TOF @ 9,698' DPM. MILL DOWN FROM 9,698'-9,699' DPM @ 9 BPM 2175 PSI,WOB=1-5K,TORQ=6-7K, RPM=75. REV/OUT @ 5 BPM 850 PSI UNTIL RETURNS CLEAN. CONT MILL AND WASH DOWN F/9,699'-9,705' @5 BPM 850 PSI,WOM = 1-5K. PUMPING DONE IN REVERSE. REV/OUT @ 5 BPM 850 PSI UNTIL RETURNS CLEAN.A TOTAL OF 50 LBS OF METAL BACK SINCE MILLING STARTED AT 01: 30 HRS. 03/13/15-Friday CONT MILL AND WASH DOWN F/9,708'-9,717' @ 5 BPM 850 PSI. RPM=75,TORQ=6-7K, WOB=1-5K.ALL PUMPING DONE IN REVERSE. PUMPING 5 BBL SWEEPS AS NEEDED. REV/OUT @ 3-1/2 BPM 450 PSI UNTIL RETURNS CLEAN.TOTAL PUMPED=120 BBLS.TOTAL METAL BACK= 149 LBS. L/D SINGLE. R/D AND LAYDOWN POWER SWIVEL. POOH SLOW W/3- 1/2" PH6& MILLING ASSY BHA TO 9,434' DPM. PRESSURE UP TO 2500 PSI ON CSG AND ATTEMPT TO INJECT INTO FORMATION. PRESSURE DROP 50 PSI IN 5 MINS THEN REMAINED @ 2450 FOR 10 MINS. N/D STRIPPER HEAD. POOH W/3- 1/2" PH6& MILLING ASSY BHA. B/D BHA. L/D(2)4-3/4" DC'S AND INSPECT MILL. MILL SHOWED INDICATION OF POSSIBLE CASING PROBLEMS. M/U RETREIVING TOOL AND PULL WEAR BUSHING.SET TEST PLUG AND R/U TEST EQUIPMENT. TEST 11"X 5M BOPS AND SURFACE EQUIPMENT AS PER AOGCC& HILCORP SPECS, 250 LOW/2500 HIGH.SEE CHART AND DETAIL SHEET DATED 3-14-15 FOR INDIVIDUAL TEST.TESTED FROM MAIN AND FUNCTION REMOTE. PERFORM KOOMEY TEST"OK".WITNESS WAIVED BY JIM REGG ON 3/11/15 @ 12 20 PM. PULL TEST PLUG.SET WEAR BUSHING AND R/D TEST EQUIPMENT. M/U 5"JUNK MILL, 5.88"STRING MILL, 3-1/2" IF PUP JT,5.88"STRING MILL,(2)4.75"JUNK BASKETS, OIL/BUMPER JARS AND(4)4-3/4 DC's.TOTAL BHA=180.31'.TIH W/3-1/2" PH6& MILLING ASSY BHA. Hilcorp Alaska LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date D-20 50-733-20203-00 169-095 2/5/15 3/22/15 Daily Operations: 03/14/15-Saturday SERVICE RIG AND SAFETY COMPLIANCE CHECK. CONT.TIH W/3-1/2" PH6 AND MILLY ASSY BHA TO 9,703' DPM. N/U STRIPPER HEAD. P/U & R/U POWER SWIVEL& EST. DRILLING PARAMETERS, PUMPING 3-1/2 BPM 500 PSI, RPM=75, TORQUE=6-7K. CONT TIH AND TAG TOP OF FISH @ 9,717' DPM. ROTATE AND WASH DOWN FROM 9,717'-9,840' DPM. (BROKE THRU @ 9,818' DPM). PUMPING 3-1/2 BPM 500 PSI,TORQ=6-7K, RPM=75, WOB=3-5K. REVERSING OUT(1)TBG VOL EVERY 30' @ 4-1/2 BPM 970 PSI. CIRCULATION DONE IN REVERSE AND DOWN TBG AS NEEDED. CONT ROTATE AND WASH DOWN FROM 9,840'-9,868' DPM,3-1/2 BPM 540 PSI, RPM=75,TORQUE=6-7K,WOB=1-5K.ALL PUMPING DONE IN REVERSE. ENCOUNTERED TIGHT SPOT @ 9,868' DPM. PIPE PLUGGING. LINE UP THE LONG WAY AND ATTEMPT TO UNPLUG PIPE "NO SUCCESS". MAKE SEVERAL ATTEMPTS, PRESSURING UP TO 1500 PSI ON BACKSIDE AND 3200 ON TBG. (SCALE, 10#METAL, OIL&GAS BACK IN RETURNS). L/D SINGLE. L/D POWER SWIVEL. N/D STRIPPER HEAD. R/U MUD BUCKET AND SWAP OUT HYD TONGS. POOH W/3-1/2" PH6 AND MILLING ASSY BHA, USING MUD BUCKET. 03/15/15-Sunday CONT POOH W/3-1/2" PH6 AND MILLING ASSY BHA. RIG DOWN MUD BUCKET. B/D& LAY DOWN BHA ON PIPERACK. WASH &CLEAN OUT DEBRIS FROM SAME. ( PIPE PLUGGED FROM OIL JARS DOWN TO BIT SUB. )JUNK MILL WAS 20% WORN. IT ALSO HAD A TORN PIECE PIPE HUNG IN FLOW COURSE AND ALSO SHOWED METAL WAS CORING OUT CENTER OF SAME. CLEAN RIG FLOOR AND PREP SAME TO TIH. P/U BHA OUT OF V-DOOR& M/U 5.50" MILL, (2)5.88"STRING MILLS,OIL/BUMPER JARS&(4)4-3/4" DC'S,TOTAL BHA=166.87'. TIH W/3-1/2" PH6 AND MILLING ASSY BHA.TORQUE GAUGE ON MCCOYS NOT WORKING PROPERLY. REMOVE SPARE GAUGE FROM TOOL LOCKER TO CHANGE OUT.SPARE GAUGE BROKEN.ATTEMPT TO REPAIR GAUGE, "NO SUCCESS". R/D MCCOY TONGS AND R/U FOSTER TONGS. TIH W/3- 1/2" PH6 AND MILLING ASSY BHA. SERVICE RIG AND SAFETY COMPLIANCE CHECK. CONT.TIH W/3-1/2" PH6 AND MILLING ASSY BHA TO 9,842' DPM. N/U STRIPPER HEAD. P/U POWER SWIVEL. MAKE CONNECTION. INSTALL STRIPPER RUBBER AND ESTABLISH DRILLING PARAMETERS, PUMPING 3 BPM 450 PSI,TORQ=5-7K, RPM=75. CON TIH &TAG TOF @ 9,863' DPM (5' HIGH). ROTATE AND WASH DOWN F/9,863'-9,866' DPM.WOB=1-8K, RPM=75 RPM,TORQUE=5-7K PUMPING 3 BPM 500 PSI. PUMPING IN REVERSE.PIPE PRESSURING UP. PU TO 9,842'& L/U LONGWAY. PUMP 5 BBL SWEEP AND DISPLACE (1) HOLE VOL W/8.8# FIW @ 5 BPM 950 PSI. RECOVERED RUBBER AND METAL AT SHAKER. CONT ROTATE& PUMPING 3 BPM 375 PSI.ALL PUMPING IN REVERSE.AND TAGGED UP AT 9,864' UNABLE TO MAKER ANY HOLE. MILL TURNING FREE, NO EXTRA TORQUE. REVERSE WELL CLEAN AND STARTED DRY DRILLING. DRY DRILLED FROM 9,864'TO 9,866'WT DOWN 5-7K RPM 75 TRQ 7K (TORQUE OFF BOTTOM =6k). la Hilcorp Alaska LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date D-20 50-733-20203-00 169-095 2/5/15 3/22/15 Daily Operations: 03/16/15-Monday CONT MILLING ON FISH F/9,866', "NO SUCCESS". UNABLE TO GET DEEPER. PUMPING 3 BPM 350 PS, RPM=75 TORQUE=6- 7K, WOB=5-10K. PIPE NOT TORQING.ATTEPT TO DRY DRILL AND SPUD ON SAME,"NO SUCCESS". LOST 2'.TAG 9,864' DPM AFTER SPUDDING. POOH TO TOP OF LINER @ 9,463' DPM. L/D SINGLES IN V-DOOR TO CHECK FOR JUNK. TIH,TAG @ 9,864' DPM, REVERSING OUT @ 3 BPM 350 PSI EVERY 60'. START MILLING ON FISH @ 9,866' DPM, (NO EXTRA TORQUE) FREE TORQUE=5-6K, RPM=75,WOB=5-10K PUMPING 2 BPM 150 PSI. DRY DRILL&SPUD ON SAME "NO SUCCESS". CIRCULATE BTMS UP @ 4-1/2 BPM 750 PSI. RECOVERD METAL SHAVINGS AND SMALL PIECES OF METAL TOTAL WEIGT=3 LBS. L/D POWER SWIVEL& N/D STRIPPER HEAD. POOH SLOW W/3-1/2" PH6 AND MILLING ASSY BHA SLOW DUE TO HIGH WINDS. SERVICE RIG& PERFORM SAFETY COMPLIANCE CHECKS. CONT'TO POOH W/3-1/2" PH6&MILL ASSY. B/D BHA& L/D SAME.JUNK MILL ROUNDED ON OUTSIDE EDGES AND WORN SLICK ON BOTTOM LIKE IT HAD BEEN A BARIUM OR SALT PILL. SLIP/CUT 90'OF DRILL LINE. RE-CALIBRATE DRAWWORKS, HMI, CROWN/FLOOR SAVERS. SET&TEST CROWN-O- MATIC"OK". SWAP PHE& PREP TO P/U BHA. GATHER PERMITS TO DRAIN &CLEAN RIG TANKS. P/U & M/U 4-3/4" BURNING SHOE, OIL/BUMPER JARS&(4)4-3/4" DC'S. 153.17'. TIH W/3-1/2" PH6&SHOE ASSY. (DRAIN/CLEAN RIG TANKS. FILL W/CLEAN 8.8 PPG FIW). 03/17/15-Tuesday N/U STRIPPER HEAD. P/U 10' PUP JT AND MAKE CONNECTION. INSTALL STRIPPER RUBBER AN ESTABLISH DRILLING PARAMETERS, PUMPING @ 7 BPM 1500 PSI, RPM=75,TORQUE=5-6 K. CONT TIH,TAG @ 9,873' DPM. ROTATE AND WASH DOWN TO 9,959' DPM @ 7 BPM, 1500 PSI,WOB=1-3K, RPM=75,TORQUE=5-6K(RECOVERING A LOT OF SCALE OVER SHAKERS). PUMP 10 BBL HI-VIS SWEEP AND DISPLACE 1 HOLE VOL WITH 8.8#F.I.W @ 5 BPM 1000 PSI. CONT ROTATE AND WASH DOWN F/9,959'-10,054' DPM, PUMPING 7 BPM 1500 PSI,TORQ=5-6K, WOB=1-3K RPM 75. (PIPE TORQUING UP). PUMP 10 BBL HI-VIS SWEEP AND DISPLACE 1 HOLE WITH 8.8#F.I.W @ 8 BPM 2000 PSI. L/D SINGLE. R/D AND L/D POWER SWIVEL. NIPPLE DOWN STRIPPER HEAD. POOH W/3-1/2" PH6&SHOE ASSY. L/D SHOE ASSY. P/U& M/U 5-1/2" TAPERED MILL,4.88"STRING MILL,OIL/BUMPER JARS,&(4)4-3/4" DC'S AS PER K.O.T. TIH W/3-1/2" PH6&TANDEM MILL ASSY.TAGGED @ 9,958' DPM.SET 5K DOWN. P/U TO 9,942' DPM& R/B STAND. N/U STRIPPING HEAD. P/U POWER SWIVEL& R/U SAME. MAKE CONN.& INSTALL STRIPPING RUBBER. BROKE CIRCULATION LONG WAY @ 9,942' BPM W/ 1400 PSI. REAMED AND WASHED FROM 9,942'TO 10,037', 75 RMP, 2-3 K DOWN. Hilcorp Alaska LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date D-20 50-733-20203-00 169-095 2/5/15 3/22/15 Daily Operations: 03/18/15-Wednesday CONT ROTATE AND WASH DOWN F/10,015'-10,045' DPM. PUMPING 6 BPM 1450 PSI, RPM=75,WOB=0 TORQ=5-6K (NORMAL). PUMP 10 BBL HI-VIS SWEEP AND DISPLACE 1 HOLE VOL. W/8.8#F.I.W @ 8 BPM 2000 PSI. POOH TO 9,430' DPM WHILE DUMPING FLUID AND CLEANING ACTIVE TANKS. FINISH CLEANING PITS AND WEIGHT UP SURFACE VOL TO 8.8#. TIH TO 10,043' DPM & R/U CIRCULATING HOSE. DISPLACE WELL W/8.8#F.I.W. @2-1/2 BPM 330 PSI UNTIL RETURNS CLEAN.ALL RETURNS GOING TO TRADING BAY.TOTAL PUMPED=800 BBLS. R/D CIRCULATING EQUIPMENT& POOH W/3- 1/2" PH6 AND MILLING ASSY TO 9,430' DPM. R/D STRIPPER HEAD. CONT. POOH W/3-1/2" PH6 AND MILLING ASSY. CONT' TO POOH W/3-1/2" PH6& MILL ASSY. B/D BHA& L/D SAME. CLEANED/CLEARED MISC EQUIPMENT FROM RIG FLOOR. HELD JSA W/CREW&ALL ESSENTIAL PERSONNEL ON P/U &TIH W/TCP GUNS.SWAPPED OUT P.H.E. & PREPARE TO P/U GUNS. P/U 4-1/2"TCP GUNS(5 SPF), SAFETY SPACER, FIRING HEAD, 1 JT 2-7/8"TBG. RECORDER CARRIER, FLOW SUB, 2 JTS OF 2-7/8 TBG, R/A SUB.TOTAL LENGTH OF BHA=734.62. SWAPPED TO 3-1/2" P.H.E.&PREP TO TIH W/PH6. TIH W/3- 1/2" PH6&TCP GUN ASSY @ 2 MIN PER STAND& DRIFTING EACH STAND OUT OF DERRICK. 03/19/15-Thursday SERVICE RIG AND SAFETY COMPLIANCE CHECK. CONT TIH W/3-1/2" PH6 AND TCP ASSY, DRIFTING SAME OUT OF DERRICK TO 9,982' DPM. SPACE OUT AND CONT TIH TO 9,992' DPM. R/U E-LINE EQUIPMENT& LUBRICATOR. M/U 5' 1-11/16" WEIGHT BAR AND 1-11/16" GAMMA RAY/CCL.TEST LUBRICATOR TO 2500 PSI. RIH W/E-LINE AND CORRELATE GUNS ON DEPTH. RA SUB @ 9,982' ELM PUTTING GUNS 10' HIGH. POOH W/E-LINE AND RIG TO THE SIDE. P/U PUP 1TS AND TIH TO 10,002' DPM. R/U E-LINE LUBRICATOR.TEST SAME TO 2500 PSI. RIH W/5' 1-11/16" ' WEIGHT BAR AND 1-11/16"GAMMA RAY/CCL AND CORRELATE GUNS ON DEPTH. CONT'TO RIH W/E-LINE&CORRELATE GUNS ON DEPTH. RA SUB @ 9,992' ELM PUTTING GUNS ON DEPTH. POOH W/E-LINE& R/D SAME. R/U CIRCULATING EQUIPMENT. DROP 10' BAR& FIRE GUNS.TOP SHOT @ 9,370' DPM & BTM SHOT @ 9,986' DPM. PUMPED 10 BBLS TO DISPLACE/FILL GUNS. MONITORED WELL"STATIC". L/D PUP JNTS& POOH W/3-1/2" PH6 TO 9,321' DPM (10 STNDS). REV/OUT 176 BBLS @ 3 BPM W/360 PSI THRU GAS BUSTER UNTIL RETURNS CLEAN.ATTEMPTED TO R/D CIRCULATING EQUIPMENT W/NO SUCCESS DUE TO EXCESSIVE U-TUBING. PUMPED 67 BBLS @ 4 BPM WITH 490 PSI THE LONG WAY. CONT'TO POOH WI 3-1/2" PH6&TCP GUN ASSY. SWAPPED P.H.E. & L/D TCP GUN ASSY.ALL GUNS OUT OF HOLE AT REPORT TIME.ALL SHOTS FIRED. PREPARING TO TEST BOP'S-WITNESS WAIVED BY MR.JIM REGG W/AOGCC 03/18/2015 @ 08: 48. Hilcorp Alaska LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date D-20 50-733-20203-00 169-095 2/5/15 3/22/15 Daily Operations: 03/20/15-Friday CLEAR RIG FLOOR OF HANDLING TOOLS FOR TCP GUNS.SERVICE RIG AND SAFETY COMPLIANCE CHECK. PULL WEARBUSING,SET TEST PLUG AND R/U TEST EQUIPMENT. TEST 11"X 5M BOPS&SURFACE EQUIPMENT AS PER HILCORP AND AOGCC SPECS 250 LOW/2500 HIGH.TEST FROM MAIN AND FUNCTION REMOTE. PERFORM KOOMEY TEST"OK". WITNESS WAIVED BY JIM REGG ON 3/18/15 @ 10: 04 A M. PULL TEST PLUG AND RIG DOWN TEST EQUIPMENT. HOLD PJSM AND REVIEW JSA W/SUMMIT AND ALL ESSENTIAL PERSONNEL ON R/U EQUIPMENT TO RUN ESP EQUIPMENT. SPOT SUMMIT EQUIPMENT IN PLACE AND RIG UP SAME. HANG SHEAVES IN DERRICK FOR CONTROL LINE AND ESP ELECTRICAL CABLE. SUMMIT M/U CTRL LINES AND ELECTRICAL CABLE TO ESP ASSY. FILL CTRL LINES&TEST SAME TO 5000 PSI "OK". P/U ESP ASSY AS PER SUMMIT REPS& M/U SAME. FILL PUMP WITH OIL& PLUG IN CABLE.TEST CONTINUITY"OK". P/U 3- 1/2"SUPERMAX TBG OUT OF V-DOOR.STRAPPED& DRIFTED EACH JOINT. INSTALLED CANNON CLAMPS ON EVERY CONNECTION FOR THE FIRST(20)JOINTS,THEN EVERY OTHER CONNECTION.CHECKED CONTINUITY EVERY 1,000'OR AS NEEDED. DEPTH @ 06:00=3,000' 03/21/15-Saturday SERVICE RIG AND SAFETY COMPLIANCE CHECK. CONT P/U 3-1/2 SUPERMAX TBG AND TIH TO 4,085'W/ESP PUMP. INSTALLING CANNON CLAMPS CHECKING CONTINUITY EVERY 1,000'.STRAP AND RABBIT SAME. SWAP OUT ELECTRICAL CABLE SPOOLERS. MAKE SPLICE. CHECK CONTINUITY"OK". CONT P/U 3-1/2 SUPERMAX TBG &TIH W/ESP PUMP. INSTALLING CANNON CLAMPS CHECKING CONTINUITY EVERY 1,000'.STRAP AND RABBIT SAME. CONT'TO P/U 3-1/2" SUPERMAX TBG&TIH W/ESP INSTALLING CANNON CLAMPS.STRAP& DRIFT EACH JOINT&CHECKING CONTINUITY EVERY 1,000'OR AS NEEDED. SPLICED CTRL LINES, ESP POWER CABLE,VENT LINE&TESTED SAME "OK". LOWERED POWER CABLE SHEAVE &SWAPPED ESP POWER CABLE REEL. CONT'TO SPLICE CABLE INTO PACKER. 03/22/15-Sunday CONTINUE MAKING SPLICE @ PACKER AND TEST SAME, "OK". HOOK UP CTRL LINES TO PACKER AND TEST SAME TO 2500 PSI FOR 5 MINS, "OK". INSTALL SCSSV AND HOOK UP CTRL LINES.TEST CTRL LINES TO 2500 PSI FOR 5MINS, "OK". FUNCTION TEST SAFETY VALVE (2)TIMES, "OK". CONT P/U 3-1/2"SUPER MAX AND TIH TO 9,361' DPM. INSTALL HGR AND M/U LANDING JT. MAKE SPLICE AND INSTALL PENETRATOR. INSTALL CTRL LINES TO HGR AND TEST SAME TO 2500 PSI FOR 5 MINS, "OK". L/D HGR. RUN IN HGR PINS AND CHECK CONTINUITY, "OK". PULL TEST CABLE AND R/U S-LINE EQUIPMENT AND LUBRICATOR. M/U 1.375" PRONG &2"JDC TOOL ON S-LINE.TEST LUBRICATOR TO 4000 PSI. RIH W/S- LINE TO 355'SLM AND SET SAME. PRESSURE UP TO 3800 PSI ON TBG FOR 30 MINS AND SET 7-5/8" HYDRAULIC PACKER 341'SLM. POOH W/S-LINE& L/D 1.375" PRONG. P/U 2.5"GS&RIH W/SAME. PULL 2.5"X-PLUG. POOH&R/D SLICK LINE EQUIPMENT. B/0 LANDING JNT& LID SAME.TERMINATE CTRL LINES&SET BPV IN HGR. BLEED DOWN KOOMEY UNIT. N/D 11"X5M BOP'S, SPACER SPOOLS, FLOW CROSS,WING VALVES& RISER. PREP HANGER& N/U PRODUCTION TREE. R/D MISC EQUIPMENT TO PREP FOR RIG SKID. VOID TESTED TREE TO 5000 PSI FOR 30 MINS, "OK".TEST TREE TO 3000 PSI, "OK". CONT'TO R/D CHOKE MANIFOLD, HOSE BOXES,V-DOOR SLIDE,CAT WALK&OTHER MISC EQUIPMENT TO PREP FOR RIG SKID. • • . MEMORANDUM State f Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg "Q `l Il Ft7I6 DATE: November 17, 2015 P. I. Supervisor 11 FROM: Lou Grimaldi SUBJECT: No Flow Test Petroleum Inspector Trading Bay Unit D-20 Hilcorp Alaska LLC PTD 1690950 Monday, November 16, 2015: I witnessed the verification test for No Flow status on Hilcorp Alaska LLC's well TBU D-20 onboard the Dolly Varden platform in the Cook Inlet. I was accompanied today by AOGCC Inspector Guy Cook. Mike Hodge (Production Operator) had the proper test equipment rigged up correctly. The test equipment consisted of; • Erdco "Armor Flo" Gas meter, Serial #022071, range 180scf-1800scf. • SSI Digital Test Gage, Serial # 1506248074, Range 0-30 psi. Calibration certificates were on hand and copies are attached to this report. The well was open to atmosphere when I arrived and there was no discernable flow. I started the test at approximately 09:30. I observed the well during two shut-in/flow cycles each of approximate equal time periods. The well exhibited less build-up and quicker discharge of said build-up pressure in subsequent test periods. It should be noted the Inner Annulus and Tubing were tied in together during the test today. The following table shows test details: Time Pressures' Flow Rate Remarks (e Icrr el) (psi) Gas - scf/hr Liquid - gal/hr 0:00 0/0/20 0 0 Flowing to atmosphere 1:30 0/0/20 0 0 Shut-in 2:15 0.9/0/20 0 0 Shut-in 3:15 1.9/0/20 0/>1800 0 Shut-in/Open to Flow 3:20 0.4/0/20 1400 0 Open to Flow 3:30 0/0/20 <180 0 Open to Flow 3:45 0/0/20 0/0 0 Open to Flow/Shut-in 4:30 0.9/0/20 0/>1800 0 Shut-in/Open to Flow 4:35 0.3/0/20 900 0 Open to Flow 4:40 0/0/20 <180 ✓ 0 Open to Flow 5:00 0/0/20 0 0 Open to Flow, no flow. 5:15 0/0/20 0 0 End test 1 Pressures are T/IA/OA Summary: This well exhibited inability to flow to surface unassisted. Attachments: Test gauge calibration certifications (2) SCANNED SEP 0 7 2.016 2015-11 16_2015-1 1 16_No-Flow_TBU_D-20_1g.docx Page 1 of 1 • • --173 zt iJo -FttaJ 11. 1,611c • • • L...HH,_,T"0 R CAL,SRATION CERTFICATic Test Equipment Traceable to NIST t_• • 2ue type: Pressure range: t , Date: - TEST PRESSURE INDICATION • • - , ; _ r-i. ;;!•''', -‘1 - • Calibrated by: Test equipment SIN: • • This cercate expires in 904:lays on - L.- \ • For recertification, contact Gina Bogart or Cathy Marshal! at KGF 776-6825. • , s- * "O" Li) St M Si 8 Palt a = = Ccn -1aa Nm ti C = _ m f!1 rill) ID. `,m -ri • a' Or+ OO qtjq =o, n m co _ ° '' ftcc, to a o ' � 0 • • A x;J ci _.t z. g-) F THE STATE °fALASKA GOVERNOR BILL WALKER Dan Marlowe Operations Engineer Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: McArthur River Field, Hemlock Oil Pool, TBU D-20 Sundry Number: 314-679 Dear Mr. Marlowe: Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www.aogcc.olaska.gov Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. �v DATED this day of January, 2015 Encl. Sincerely, AthyP.' oerster Chair 5CANNED Jiilr f"� 171 STATE OF ALASKA O:S'M ALASKA OIL AND GAS CONSERVATION COMMISSION MjI5 APPLICATION FOR SUNDRY APPROVALS 2n AAr. 9-,9Rn RECEIVED DEC 2 2 2014 LL .��s`s AOGGC 1. Type of Request: Abandor ❑ Plug for Redrill ❑ Perforate New Pod 0' Repair Well ❑ Change Approved Program ❑ Suspend ❑ Plug Perforations ❑ Perforate 0 Pull Tubing Q Time Extension ❑ Operations Shutdowr ❑ Re-enter Susp. Well 0 Stimulate ❑ Alter Casing 0(her. Install ESP 0 2. Operator Name: 4. Current Well Class: 5. Perm it to Drill Number: Hilcorp Alaska, LLC Exploratory ❑ Development Stratigraphic ❑ Service ❑ 169-095 3. Address: 3800 Centerpoint Drive, Suite 1400 6. API Number: Anchorage, AK 99503 50-733-20203-00 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? CO 228A - Will planned perforations require a spacing exception? Yes ❑ No F Trading Bay Unit / D-20 9. Property Designation (Lease Number): 10. Field/Pool(s): ADL0018729 I McArthur River Field / Hemlock Oil Pool 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 10,506 10,028 1 1 4,200 2,704 4,200 N/A Casing Length Size MD TVD Burst Collapse Structural Conductor 400' 33" 400' 399' Surface 3,006' 13-3/8" 3,006' 2,905' 3,090 psi 1,540 psi Intermediate Production 9,674' 9-5/8" 9,674' 9,242' 5,750 psi 3,090 psi Liner 1,017' 7" 10,480' 10,003' 8,160 psi 7,020 psi Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): See Schematic See Schematic 3-1/2" 9.2# / L-80 2,792 Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): See Schematic See Schematic 12. Attachments: Description Summary of Proposal 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch (] Exploratory L-1 Stratigraphic ❑ Development ❑ Service ❑ 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: 1/15/2015 Oil Q Gas ❑ WINJ ❑ GINJ ❑ WDSPL ❑ Suspended ❑ WAG ❑ Abandoned ❑ 16. Verbal Approval: Date: Commission Representative: GSTOR ❑ SPLUG ❑ 17. 1 hereby certify that the aforegoing is true and correct to the best of my knowledge. Contact Dan Marlowe Email dmarlovve@hiIggD.Com Printed Name Dan Marlowe Title Operations Engineer Signature_.tom-- ec Phone 907 283-1329 Date 12/22/2014 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: �� C�j� t— C Spacing Exception Required? Yes ❑ No ❑ Subsequent Form Required: Ll /% APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: Form 10-403 (Revised 10/2012) QrRd�&'fINAijfor 12 months from the date of approval. R13C MS .JAN - 9 20?5, Submit Form and Attachments in Duplicate I � U Hilcorp Alaska, LLC Well Work Prognosis Well: D-20 Date: 12/22/2014 Well Name: D-20 API Number: 50-733-20203-00 Current Status: Suspended Leg: Leg #13-1 (SE corner) Estimated Start Date: January 15, 2015 Rig: HAK #1 Reg. Approval Req'd? 403 Date Reg. Approval Rec'vd: Regulatory Contact: Juanita Lovett Permit to Drill Number: 169-095 First Call Engineer: Dan Marlowe Office: 907-283-1329 Cell: 907-398-9904 Second Call Engineer: Ted Kramer Office: 907-777-8420 Cell: 985-867-0665 Current BHP: — 3,628 psi @ 9,450' TVD 0.384 psi/ft, (7.40 ppg) bottom of HK Max. Expected BHP: — 3,970 psi @ 9,450' TVD 0.42 psi/ft, (8.10 ppg) add G zone perfs Max. Possible SP: 0 psi Well will not flow based on an expected oil and water gradient of 0.437 psi/ft Brief Well Summary D-20 is a suspended Hemlock zone producer that was last produced via a gas -lift completion. This work - over will remove the kill string, cleanout, run a liner back to surface, and run an ESP completion. The D-27 well collided with D-20 in 1975 and a 7" liner was installed tying back from 1,723' to surface. The casing strings began communicating again in 2005 and the well was shut-in. A work -over in 2007 attempted to repair the well but found additional holes at 4276' at which time the well was suspended. 19 Procedure: 1. RU HAK Rig 1 over D-20. 2. Notify AOGCC 48 hours before pendin BOPE test. Set BPV, ND tree, NU BOPE. Test all BOP equipment per AOGCC guidelines t 0 psi LOW and 2,500 psi HIGH. 3. PU landing joint and make-up to bing hanger. Circulate any hydrocarbons from the well. 4. POOH; LD tubing. 5. Mill up ment retainer and bridge plug cleaning out to top of liner at 9,463'. 6. Run and ce ent a tie back liner to surface. 79E �7. Cleanout to t of roduction packer at 9,601'. 6 8. Pressure test ca g against production packer at 9,601' to —2,500 psi and chart for 30 minutes. (r 9. Run a ceme on -log from 9,500' to surface. 10. Remove duction packer at 9,601' and cleanout well to -10,000' 11. PU TCP uns and RIH and re -perforate the G and Hemlock zones per the Perf Recommendation. 12. Aft detonation, circulate perf gas, confirm well is static, POOH. 13. n ESP completion. 1 . Set BPV. NU tree, test same. 5. Schedule the no flow AOGCC within 2 weeks of stable production as per regulations. Attachments: 1. Current Well Schematic 2. Proposed Well Schematic 3. Current Wellhead Diagram 4. Proposed Wellhead Diagram 5. BOP Stack - Primary 6. BOP Stack — w/ Extra Ram's for running casing Chevron Trading Bay Unit Well # D-20 Suspension RKB to TBG Head = 41.8' Tree connection: 4-1/6" 5.000# PBTD = 10,430' TO = 10,506' MAX HOLE ANGLE = 21°, @ 2100' C as in a & T u b in a Size Type Wt Grade Thrd ID Top Btm Hole Cott Cmt Top 33" Conductor Fasdrill Retainer. 10,506 4320' NA Surf 400' Driven 4.0 Baker "FB -1" Pkr. w/ 10' Seal bore ext. & bell guide, w/ "SB" Pkr Plu 2 10,068' 3.25 Baker Model "D" Pkr. -------- 16 10,078' 2.75 Otis "X" Nipple, size 2.75 2350 sx Surf 13-3/8" Surf Csg 61 K-55 Seal Lock 12.515 Surf 3006' 17-1/2" 150 sx Top 2500 sx Total Open f/ Production 40 10,230' Mule Shoe 8.835 Surf 4390' Open f/ Production 80 bbls cmt returns 9-5/8" Prod Csg N-80 Butt 43.5 8.755 4390' 5204' 5206' 5204' 5206' 6156' 12-1/4" 1000 sx CBL Good Bond 2000' 5200' DV Collar 43.5 8.755 N-80 CBL 9-5/8" Prod Csg Butt 6156' 7080' 1700 sx Good Bond S-95 47 8.681 7080' 9072' 8450' 9450' AR -95 Seal Lock 9072' 9674' 9960' TOC 375 sxs ' -9669' & 96639677'-9680' 7" Liner 29 N-80 X -Line 6.185 9463' 10,480" 8-1/2" & ImIudes (2) sqz 9744'-9749' CBL Tubing 41.8' RKB to Tbg Hngr 3-1/2" Kill String 1 9.2 1 N-80 I Butt 2.992 Surf 2792' 1FWFI.RV nl TAI[. NO. De th ID Item -Approximate Rotating hrs: 0 3050' CIW 4-1/2" EUE 8rd X Butt Tbg. Hanger. 0 12-1/4" to 4200' NA Fasdrill Retainer. 10,506 4320' NA Fasdrill Bridge Plug 1 9,601 4.0 Baker "FB -1" Pkr. w/ 10' Seal bore ext. & bell guide, w/ "SB" Pkr Plu 2 10,068' 3.25 Baker Model "D" Pkr. -------- 16 10,078' 2.75 Otis "X" Nipple, size 2.75 9,950' 10,086' 3.00 Bell Guide 3 10,198' 3.25 Baker Model "D" Pkr. 10,190' 10,206' 2.625 Otis "Q" Nipple, size 2.625 Open f/ Production 10,212' 10,230' Mule Shoe RAf rlrtailc R Infn- Tn date Spudded D-20 on 9/20/69. TD @ 10,506' on 10/25/69. Com leted & RR on 11/06/69. -Hole Section MWT: Amt. -Approximate Rotating hrs: 0 17-1/2" to 3050' 9.9 to 10 ppg 0 33" 60 hrs 0 12-1/4" to 9,748' 9.8 to 10 ppg 0 13-3/8" 285 hrs 0 8-1/2" to 10,506 o 9-5/8" 51 hrs 9,820' 9,885' o 7" 16 hrs PFRF"12ATinN iIATA Zone Top Btm Amt. Accum SPF Last Perf Date Present Condition Sqz 9,750' 9,751' 1' 4 10/30/1969 Sqz 75 sx cmt. B-1 9,820' 9,885' 65' 20 6/15/1992 Open f/ Production B-3 9,905' 9,950' 45' 16 6/15/1992 Open f/ Production B-4 1 9,950' 10,065' 115' 16 6/15/1992 Open f/ Production B-5 10,070' 10,190' 120' 16 Jul -75 Open f/ Production B-6 10,230' 10,260' 30' 4 Jul -75 Open f/ Production D-20 Schematic 2007-03-29 CRW: 3/29/2007 Trading Bay Unit PROPOSED well: D-20 Ili leorpAlaska. LLC Completed: Future RKB to TBG Head = 41.8' Tree connection: 4-1/6" 5 /a1 316 J N..luy on 2v16" thru pkr. Aurin" WO in 11163 Crnt Ret @4200' 3P @ 4320' ('ACINI(: nl:TAII SIZE TYPE WT GRADE CONN ID TOP BTM. 33" Conductor 0 7" 16 hrs Bottom of ESP 2 1 10,068' 3.25 Surf 400' 13-3/8" Surf Csg 61 K-55 Seal Lock 12.515 Surf 3006' 9-5/8" Prod Csg 40 N-80 Butt 8.835 Surf 4390' Future 43.5 9,680' 9,681' 8.755 4390' 5204' DV 11/2/1969 Sqz 100 sx cmt. Sqz 9,750' 9,751' 5204' 5206' Collar 4 10/30/1969 Sqz 75 sx cmt. HK -1 9,820' 9,885' 9,381' 9,442' 65' 43.5 N-80 Open f/ Production 8.755 5206' 6156' ±9,388' ±9,420' ±34' S-95 Butt Future 6156' 7080' 9-5/8" Prod Csg 47 45' 16 8.681 7080' 9072' ±9,908' ±9,932' ±9,464' AR -95 Seal Lock 9072' 9674' 7-5/8" Liner 29 L-80 SLIJ-II 115 Surf ±9,463' 7" Liner 29 N-80 X -Line 6.185 9463' 10,480' TUBING DETAIL 3-1/2" 9.2 L-80 1SuperMax 2.992 Surf ±9200' c 1.15JEWELRY DETAIL G-1 G-4 hCS9 shoe ; @9660'DIL HKA 2 3 PBTD = 10,430' TD = 10,506' MAX HOLE ANGLE = 21°, @ 2100' NO. Depth ID item 0 o 33" 60 hrs CIW 4-1/2" EUE 8rd X Butt Tbg. Hanger. o 13-3/8" 285 hrs 0 8-1/2" to 10,506 0 9-5/8" 51 hrs 1 ±9,300 0 7" 16 hrs Bottom of ESP 2 1 10,068' 3.25 Baker Model "D" Pkr. 10,078' 2.75 Otis "X" Nipple, size 2.75 10,086' 3.00 Bell Guide 3 10,198' 3.25 Baker Model "D" Pkr. 10,206' 2.625 Otis "Q" Nipple, size 2.625 10,212' ±9,057' Mule Shoe n-._[ --- O ...6... T.- A- Spudded D-20 on 9/20/69. TD @ 10,506' on 10/25/69. Completed & RR on 11/06/69 - .Hole Section MWT: -Approximate Rotating hrs: 0 17-1/2" to 3050' 9.9 to 10 ppg o 33" 60 hrs 0 12-1/4" to 9,748' 9.8 to 10 ppg o 13-3/8" 285 hrs 0 8-1/2" to 10,506 0 9-5/8" 51 hrs Btm(MD) 0 7" 16 hrs 4/29/75 D-27 collided w/ D-20 while drilling 17-1/2" surface hole. Communication to Inlet Spotted 500sx of G curt @ 400' in D-27. Possible length of breach in 13-3/8" is 1488' to 1497'. Penetration in D-20 9-5/8" @ 1497'. 7/75 WO sqz'd 9-5/8" csg @ 1497' 4x. Total cmt placed 650 sx. Updated: 12/22/14 by JUL PERFORATION DETAIL Zone (Mp) Btm(MD) Top (TVD) Btm (TVD) Amt. SPF Last Perf Date Present Condition G-1 ±9,370' ±9,388' ±8,955' ±8,972' ±18' Future G-4 ±9,478' ±9,484' ±9,057' ±9,063' ±6' Future Sqz 9,680' 9,681' 9,248' 9,249' 1' 4 11/2/1969 Sqz 100 sx cmt. Sqz 9,750' 9,751' 1 9,315' 9,315 1' 4 10/30/1969 Sqz 75 sx cmt. HK -1 9,820' 9,885' 9,381' 9,442' 65' 20 6/15/1992 Open f/ Production HK -1 ±9,828' ±9,862' ±9,388' ±9,420' ±34' Future HK -3 9,905' 9,950' 9,461' 9,503' 45' 16 6/15/1992 Open f/ Production HK -4 ±9,908' ±9,932' ±9,464' ±9,486' ±2q' Future HK -4 9,950' 10,065' 9,503' 1 9,611' 115 16 6/15/1992 Open f/ Production HK -4 ±9,964' ±9,986' ±9,516' ±9,537' ±22' Future HK -5 1 10,070' 1 10,190' 9,616' 9,730' 120' 16 Jul -75 Open f/ Production HK -6 10,230' 10,260' 9,767' 9,796' 30' 4 Jul -75 Open f/ Production 4/29/75 D-27 collided w/ D-20 while drilling 17-1/2" surface hole. Communication to Inlet Spotted 500sx of G curt @ 400' in D-27. Possible length of breach in 13-3/8" is 1488' to 1497'. Penetration in D-20 9-5/8" @ 1497'. 7/75 WO sqz'd 9-5/8" csg @ 1497' 4x. Total cmt placed 650 sx. Updated: 12/22/14 by JUL Dolly Varden Platform D-20 Current 02/02/2012 Hilcwp Uu.ka. Uk Dolly Varden D-20 13 3/8 X 9 5/8 X 3 1/2 Valve, Master, FMC -120, 3 1/8 5M FE, HWO, AA trim Tubing head, CIW-DCB, 13 5/8 3M X 11 5M, w/ 2- 2 1/16 5M SSO, X bottom Casing head, CIW-WF, 13 5/8 3M X 13 3/8 casing thread bottom, w/ 2- 2 1/16 5M EFO, CA slips installed in head I' , BHTA, FMC, B -15-A, 3 1/8 5M FE Tubing hanger, CIW-DCB- FBB, 11 X 3 % EUE lift X 3 % BTC susp, w/ 3" type H BPV, 1/8 non continuous control line, 6 1/4" extended neck prep Valve, WKM-M, 2 1/16 5M FE, HWO, AA trim , s �. Qty 2 %0 Ig 0 0 Valve, CIW-F, 2 1/16 5M FE, HWO, AA trim Hlrnrp \larkn- LL(. Dolly Varden Platform D-20 Proposed 12/19/2014 Dolly Varden Tubing hanger, FMC -TC -ESP, D-20 11 X 3 h NS -CT lift and susp, 13 3/8 X 9 5/8 X 7 5/8 X 300-4 seal pocket, w/ 3" 27/8 Type H BPV profile, 2- 3/8 CCL, Alloy material BHTA, Bowen, 3 1/8 5M FE X 3" Bowen Quick Union Valve, swab, WKM-M, 31/8 5M FE, HWO, T-24 Valve, WKM-M, 3 1/8 5M FE, w/ 15" OMNI operator Valve, wing, WKM-M, 2 1/16 5M FE, HWO, T-24 *7t Valve, lower master, WKM-M, r— 3 1/8 SM FE, HWO, T-24 all Adapter, FMC -A -S -EC, 115M rotating flange x 31/8 5M rotating top, 300-4 pocket prep, 2- CCL ports, 3.266 centers Multibowl wellhead assy, Cactus MBS -2 Valve, WKM-M, 2 1/16 SM FE, 13 5/8 3M x 11 5M, w/4- t HWO, D O 21/16 5M SSO, prepped for 7 5/8 mandrel hanger, and tubing hanger, 9 5/8 HIP bottom i w Valve, WKM-M, 2 1/16 5M FE, HWO, DD Casing head, CIW-WF, Valve, CIW-F, 21/16 3M FE, 13 S/8 3M X 13 3/8 casing HWO, AA trim thread bottom, w/ 2- 21/16 5M EFO Ifil—vp %In.LA_ LII Dolly Varden Platform 2014 Workovers BOP Drawing (HAK#1) Quail Tool Rental Stack Dolly Varden Platform 2014 BOP Stack (HAK #1) 01/10/2014 Dolly Varden Platform D-20 BOP drawing 09/02/2014 Dolly Varden Platform BOP Drawing (HAK #1) Quail Tool Rental Stack I-5 variables ids rams Hileorp Ala-ka. LLC Attachment #1 Hilcorp HAK #1 BOP Test Procedure Attachment #1 Hilcorp Alaska LLC. BOP Test Procedure: Hilcorp HAK #1, Dolly Varden WO Program — Oil Producers, Water Injectors Pre Rig Move 1) Blow down well, bleed gas to Well Clean Tank that is vented thru flare to atmosphere 2) Load well with FIW to kill well. • Note: Fluid level will fall to a depth that balances with reservoir pressure. 3) Shoot fluid level at least 24 hours before moving on well. 4) Shoot fluid level again, right before ND/NU. Confirm that well is static. Initial Test (i.e. Tubing Hanger is in the Wellhead) If BPV profile is good 1) Set BPV. ND Tree. NU BOP. 2) MU landing joint. Pull BPV. Set 2 -way check in hanger. 3) Space out test joint so end of tubing (EOT) is just above the blind rams. 4) Set slips, mark same. Test BOPE per standard test procedure. If BPV profile is eroded and/or corroded and BPV cannot be set with tree on, Profile and/or landing threads must be prepped while tree is off. Worst Case: BPV profile and landing threads are bad. 1) Attempt to set BPV through tree. If unsuccessful, shoot fluid level. 2) If fluid level is static from previous fluid level shots, notify Hilcorp Anchorage office that the well is static and the tree must be removed with no BPV. As approved in the sundry, proceed as follows: a) ND tree with no BPV b) Inspect and prepare BPV profile to accept a 2 -way valve, or prepare lift -threads to accept landing joint to hold pressure. If well is a producer and the culprit is scale, attempt to clean profile with Muriatic acid and a wire brush or wheel. c) Set 2 -way check valve by hand, or MU landing (test) joint to lift -threads d) NU BOP. Test BOPE per standard procedure. 3) If both set of threads appear to be bad and unable to hold a pressure test, notify Operations Engineer (Hilcorp), Mr. Guy Schwartz (AOGCC) and Mr. Jim Regg (AOGCC) via email explaining the wellhead situation prior to performing the rolling test. AOGCC may elect to send an inspector to witness. As outlined and approved in the sundry, proceed as follows: a) Nipple Up BOPE b) With stack out of the test path, test choke manifold per standard procedure c) Conduct a rolling test: Test the rams and annular with the pump continuing to pump, (monitor the surface equipment for leaks to ensure that the fluid is going down -hole and not leaking anywhere at surface.) Hilcorp Alaska, LIT Hilcorp HAK #1 BOP Test Procedure Attachment #1 d) Hold a constant pressure on the equipment and monitor the fluid/pump rate into the well. Record the pumping rate and pressure. e) Once the BOP ram and annular tests are completed, test the remainder of the system following the normal test procedure (floor valves, gas detection, etc.) f) Record and report this test with notes in the remarks column that the tubing hanger/BPV profile wouldn't hold pressure and rolling test was performed on BOP Equipment and list items, pressures and rates. 4) Pull hanger to surface. (Requires tubing cuts as necessary to free tubing). CBU to displace annulus and tubing with kill weight fluid. 5) If a rolling test was conducted, remove the old hanger, MU new hanger or test plug to the completion tubing. Re -land hanger (or test plug) in tubing head. Test BOPE per standard procedure. Subsequent Tests (i.e. Test Plug can be set in the Tubing -head) 1) Remove Wear bushing. a) Use inverted test plug to pull wear busing. MU to 1 jt. of tubing. b) Thread into wear bushing c) Back out hold down pins d) Pull and retrieve wear bushing. 2) Break off test plug and invert same, and RIH on 1 joint of tubing. Install a closed TIW or lower Kelly valve in top of test joint. 3) Break joint off test plug and pull up to space the bottom of tool joint above blind rams. 4) Test BOPE per standard procedure. STANDARD BOPE TEST PROCEDURE (after 2 -way check or test plug is set) 1) Fill stack with rig pump and install chart recorder on the stack side of the pump manifold. 2) Note: When testing, pressure up with pump to desired pressure, close valve on pump manifold to trap pressure and read same with chart recorder. 3) Referencing the attached schematics test rams and valves as follows. a) Close C-2 (inside gate valve on choke side of mud cross) and close the annular preventer. Pressure test to 200 psi for 5 minutes and 1,500 psi high for 5 minutes. If passes after 5 minutes on each, bleed off back to tank and open annular. b) Close Pipe Rams. Test to 200 psi for 5 minutes and 3,000 psi high for 5 minutes. If passes after 5 minutes on each, bleed off back to tank and open pipe rams. c) Test Dual Rams. If the well has dual tubing, and dual rams are installed in the stack, test the dual rams by picking up two test joints with dual elevators and lowering them into stack and position them properly in the dual rams. Close rams. Test to 200 psi for 5 minutes and 3,000 psi for 5 minutes. If passes after 5 minutes on each, bleed off back to tank and open rams. d) Open C-2. Flow through the choke manifold and purge air. Test the choke manifold starting with the outer most valves, to 250 psi low and 3,000 psi high, for 5 minutes each, as follows: (Valve numbers are in reference to Diagram B) i) Valves 1, 2, 10. After test, open same. Hilrnrp Alaska, LLC Hilcorp HAK #1 BOP Test Procedure Attachment #1 ii) Valves, 3, 4, 9. After test, open valves 3 & 4. Leave 9 closed. iii) Valves 5, 6, 9. After test, open valves 5 & 6, leave 9 closed. iv) Valves, 7, 8, 9. After test, open all valves. e) Close C-3. This is the HCR (the hydraulic controlled remote) valve just outside C-1 on choke side of mud cross. Test to 250 psi low and 3,000 psi high. After test, open HCR, close C-1. f) Blind Rams. Make sure test joint is above the blind rams. Close blind rams. Test to 200 psi Low for 5 minutes and 3,000 psi High for 5 minutes. Bleed down pressure. g) Bleed off all pressure. Line up pumps to pump down tubing. h) Test C-1, C-2, and C-4 on the kill (pump -in) side by pressuring up on tubing. Test to 200 psi Low for 5 minutes and 3,000 psi High for 5 minutes. i) Test floor valves TIW (or Lower Kelly Valve) and IBOP. STANDARD TEST PROCEDURE OF CLOSING UNIT (ACCUMULATOR) 1) This is a test of stored energy. Shut off all power to electric and pneumatic pumps. 2) Record "Accumulator Pressure". It should be +/- 3,000 psi. 3) Close Annular Preventer, the Pipe Rams, and HCR. Close 2nd set of pipe rams if installed (e.g. dual pipe rams). Open the lower pipe rams to simulate the closing volume on the blinds. 4) Allow pressures to stabilize. 5) While stabilizing: Record pressure values of each Nitrogen bottle and average over the number of bottles. (i.e. Report might read "10 bottles at 2,150 psi"). 6) After accumulator has stabilized, record accumulator pressure again. This represents the pressure and volume remaining after all preventers are closed. (The stabilized pressure must be at least 200 psi above the pre -charge pressure of 1,000 psi). 7) Turn on the pump and record the amount of time it takes to build an additional 200 psi on the accumulator gauge. This is usually +/- 30 seconds. 8) Once 200 psi pressure build is reached, turn on the pneumatic pumps and record the time it takes for the pumps to automatically shut-off after the pressure to builds back to original pressure (+/- 3,000 psi). Note: Make sure the electric pump is turned to "Auto", not "Manual' so the pumps will kick-off automatically. 9) Open all rams and annular and close HCR to place BOPE back into operating position for well work. 10) Fill out AOGCC report. FINAL STEP, FINAL CHECK 1) Test Gas Alarms 2) Double check all rams and valves, for correct operating position 3) Fill out the AOGCC BOPE Test Form (10-424) in Excel Format and e-mail to AOGCC and Juanita Lovett. Hilcorp HAK #1 BOP Test Procedure Harnrp un=k�. i.t.c Attachment #1 Diagram A: Dolly Varden BOP stack and Riser Arrangement — Typical for Single Completion Dolly Varden Platform r let 2014 BOP Stack ("AK #1) XM/ wl 01/10/2014 HAI. Dolly Varden Platform 2014 Workovers BOP Drawing)HAK #1) Quail Tool Rental Stack Hilcorp Alaska, III Diagram B: Dolly Varden Choke Manifold Hilcorp HAK #1 BOP Test Procedure Attachment #1 From Bop Choke Line 2 1/16 5M Unibolt Flange FLUID FLO',,N DIAGRAM NORMAL OPERATIONS CIRCULA z > w m r+O_ v � 3 x N � N CL c N m FLUID FLOW DIAGRAM NORMAL OPERATIONS CIRCULATING DO'bV'N TUBING, UP CASING ANNULAS 'THE LONG v% -AY" MUD PUMP PUMP MANIFOLD LP SUCTION LINE W" - a Lem FLUID T„ NVOPIT P,:tilc LINE TRVIER T ACIP VANVALJ `n+fSO K.7c C NO KE CMO bm STACK •MCR VALVE D W 2 '* O - °; o S m "o m rr 2 N ^ N CL c m Schwartz, Guy L (DOA) From: Dan Marlowe <dmarlowe@hilcorp.com> Sent: Tuesday, December 30, 2014 3:57 PM To: Schwartz, Guy L (DOA) Subject: RE: D-20 RWO (PTD 169-095) Guy Additional details below per your request, Let me know if you have any further questions. Procedure: 1. RU HAK Rig 1 over D-20. 2. Notify AOGCC 48 hours before pending BOPE test. Set BPV, ND tree, NU ROPE. Test all BOP equipment per AOGCC guidelines to 250 psi LOW and 2,500 psi HIGH. 3. PU landing joint and make-up to tubing hanger. Circulate any hydrocarbons from the well. 4. POOH, LD tubing. • PU storm packer, RIH and set same at 200' and hang off string. Pressure test to 1,500 psi and chart. • Release from storm packer, POOH. Remove tubing head and install Casing spool. • Test all flange breaks to 2,500 psi and chart. • RIH, engage storm packer, release same, POOH, LD storm packer. 5. Mill up cement retainer and bridge plug cleaning out to top of liner at 9,463'. • Hang off and cut liner • Pressure test liner to -2,500 psi and chart for 30 minutes. • Install new tubing spool • Test all flange breaks to 2,500 psi and chart. 7. Cleanout to top of production packer at 9,601'. 8. I)FessuFe -asing ag,,ainst pFeductieR pael(eF at 9,601' to -2,50 -Rd Chain fA. 30..... F 9. Run a cement bond log from 9,500' to surface. C /6L 10. Remove production packer at 9,601' and cleanout well to 10,000' 11. PU TCP guns and RIH and re -perforate the G and Hemlock zones per the Perf Recommendation. 12. After detonation, circulate perf gas, confirm well is static, POOH. 13. Run ESP completion. 14. Set BPV. NU tree, test same. 15. Schedule the no flow AOGCC within 2 weeks of stable production as per regulations. From: Schwartz, Guy L (DOA) [ma iIto: guy. schwa rtz alaska.gov] Sent: December 30, 2014 1:59 PM To: Dan Marlowe Subject: D-20 RWO (PTD 169-095) Dan, Please send email modification to the procedure that includes the wellhead tubing spool swap. Make sure it includes how the flange breaks with be pressure tested. Guy Schwartz Senior Petroleum Engineer AOGCC 907-301-4533 cell 907-793-1226 office CONFIDENTIALITY NOTICE. This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Guy Schwartz at (907-793-1226) or (Guv Schwartz@alaska.aov). Imagei~' ~ject Well History File Cover P!i ; XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. ~_~_- _~ ~ Well History File Identifier Organizing RESCAN DIGITAL DATA OVERSIZED (Scannable) [] Color items: [] Diskettes, No. [] Maps: [] Grayscale items: [] Poor Quality Originals: [] Other: NOTES: [] Other, No/Type BY: BEVERLY ROBIN VINCENT SHERYL MARIA FINDY ~) Project Proofing BY: BEVERLY ROBIN VINCENT SHERYL~INDY Scanning Preparation x 30 = ~.~(~ BY: BEVERLY ROBIN VINCENT SHERYF MAR~ ~,~INDY~ Production Scanning Stage I Other items scannable by large scanner OVERSIZED (Non-Scannable) [] Logs of various kinds [] Other DATE: ' BY: Stage 2 BY~ (SCANNING IS COMPLETE AT THiS POINT UNLESS SPECIAL. ATTENTION IS REQUIRED ON AN INDIVIDUAL PAGE BASIS' DUE TO QUALITY, GRAYSCALE OR COLOR IMAGES ) PAGE COUNT FROM SCANNED FILE: PAGE COUNT MATCHES NUMBER IN SCANNING PREPARATION' YES IF NO IN STAGE 1 ~ PAGE(S) DISCREPANCIES WERE FOUND: YES . NO BEVERLYtC~_'.~ VINCENT SHERYL MARIA WINDY DATE:/.?~ 0:-~__~ RESCANNEDBY: BEVERLY ROBIN VINCENT SHERYL MARIA WINDY General Notes or Comments about this file: DATE: IS/ Quality Checked 12/10/02Rev3N OTScanned.wpd • • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Suspended Well Inspection Report Date Inspected: 09/23/10 Inspector: Lou Grimaldi Operator: Union Oil Company Well Name: TBU D -20 • Oper. Rep: Mike Rogde PTD No.: 169 -095 Oper. Phone: 907 - 776 -6840 Location Verified? Yes Oper. Email: If Verified, How? Other (specify in comments) Onshore / Offshore: Offshore Suspension Date: 01/31/07 Date AOGCC Notified: 09/21/10 Sundry No.: 307 -032 Type of Inspection: Initial Wellbore Diagram Avail.? Yes Well Pressures (psi): Tubing 0 (vac) Photos Taken? Yes IA 1 OA 64 � • _ • Condition of Wellhead: Good. No flowline. Wellhead in apparent good condition. ' Condition of Surrounding Surface Wellroom clean and orderly. Location: Follow Up Actions None ' Needed: Attachments: Photos (2) REVIEWED BY: J �� j Insp. Supry / /( ( >2 Comm PLB 09/2010 2010- 0923_Suspend_TBU_D- 20_Ig.xls Suspended Well Inspection – Trading Bay Unit D -40 PTD 1690950 Photos by AOGCC Inspector L. Grimaldi . 'id er � m r -,., _ - — ''. .t. 411 _ ____ _ fi - ,oltv,, ... ,t4i.u. • ,......,,.h,,.. . , : . „ 0 .,,,, \-.- .... _ . ... . .,. ... . .c tl, . ... Li :' . r 1. 00 i t ,4r tar ter' f ,._ 1 .. WA STATE OF ALASKA l `X1114 ALASK� AND GAS CONSERVATION COMMISSik REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon Li Repair Well LJ Plug Perforations Ll Stimulate Ll Other ✓ Suspended Well Performed: Alter Casing ❑ Pull Tubing ❑ Perforate New Pool ❑ Waiver ❑ Time Extension ❑ Inspection Change Approved Program ❑ Operat. Shutdown ❑ Perforate ❑ Re -enter Suspended Well ❑ 2. Operator Union Oil Company of California 4. Well Class Before Work: 5. P` rmit to Drill Number: Name: Development ❑✓ Exploratory ❑ 169 -095 3. Address: PO Box 196247, Anchorage, AK 99519 Stratigraphic❑ Service ❑ 6. API Number: 50- 733 - 20203 -00 00 7. Property..Designation (Lease Number): 8. Well Name and umber: ADL0018729 [Dolly Varden Platform] Trading Bay Unit D -20 r 1 �!t/ULC -CY 9. Field /Pool(s): McArthur River Field / Hemlock Oil Pool 10. Present Well Condition Summary: Total Depth measured 10,506 feet Plugs (measured) 4,200' (Cement) feet true vertical 10,028 feet Junk (measured) N/A feet Effective Depth measured 4,200 feet Packer (measured) N/A feet true vertical 2,704 feet (true vertical) N/A feet Casing Length Size MD TVD Burst Collapse Structural Conductor 400' 33" 400' 399' Surface 3,006' 13 -3/8" 3,006' 2,905' 3,090 psi 1,540 psi Intermediate Production 9,674' 9 -5/8" 9,674' 9,242' 5,750 psi 3,090 psi Liner 1,017' 7" 10,480' 10,003' 8,160 psi 7,020 psi Perforation depth: Measured depth: N/A MY 2 True Vertical depth: N/A Tubing (size, grade, measured and true vertical depth): 3 -1/2" 9.2# N -80 2,792'MD 2,704'TVD Packers and SSSV (type, measured and true vertical depth): N/A N/A N/A N/A 11. Stimulation or cement squeeze summary: Intervals treated (measured): rr02010 N/A Treatment descriptions including volumes used and final pressure: Ud 12. Representative Daily Average Production or Injection DIMOrage Oil -Bbl Gas -Mcf I Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 0 10 0 psi 0 psi Subsequent to operation: 0 0 10 10 psi 0 psi 13. Attachments: 14. Well Class after work: Copies of Logs and Surveys Run N/A Exploratory❑ Deve opment ✓❑ Service ❑ Daily Report of Well Operations N/A 15. Well Status after work: W V Oil Gas Lj WDSPL Well Remains in 'SUSP' Status = => GSTOR ❑ WAG ❑ GINJ ❑ WINJ ❑ SPLUG ❑ 16. 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: N/A Contact Chris Kanyer 263 -7831 Printed Name Timothy C. Brandenburg Title Drilling Manager Signature Phone 276 -7600 Date 10/11/10 DMS OCT 21 M$ Form 10 -404 Revised 7/2009 Submit Original Only Suspended Well Inspection Data Well: D -20 Surface Location: 672.1' FSL, 1211.1' FWL, Sec 6, TBN, R13W S.M. Permit to Drill: 169 -095 API: 50- 733 - 20203 -00 AOGCC Inspection Date: 9/23/10 AOGCC Inspector: Lou Grimaldi Size Pressure (psi) Tubing 3 -1/2" 0 Casing 9 -5/8" 0 13 -3/8" 64 *Note: Wellhead pressures to be recorded monthly at minimum. Other Notes: • Wellhead good, no flow line. Wellhead in apparent good shape. Clean wellroom. Attachments: • Current Well Schematic • Picture(s) • Plat - 1 /4mile radius of wellbore • Correspondence /Suspended Well Inspection Report Chevron +• . Trading Bay Unit Well # D -20 Suspension RKB to TBG Head = 41.8' Tree connection: 4 -1/6" 5,000# < Casing & Tubing Size Type Wt Grade Thrd ID Top Btm Hole t 33" Conductor Surf 400' Driven At 13 -3/8" Surf Csg 61 K -55 Seal Lock 12.515 Surf 3006' 17 -1/2" 40 8.835 Surf 4390' 9 -5/8" Prod Csg 43.5 N -80 Butt 8.755 4390' 5204' DV Collar 5204' 5206' 43.5 8.755 5206' 6156' 12 -1/4" N -80 Butt 6156' 7080' Cmt R et 9 - 5/8" Prod Cs 04200' g 47 S -95 8.681 7080' 9072' AR -95 Seal Lock 9072' 9674' BP @ 4320' 7" Liner 29 N -80 X -Line 6.185 9463' 10,480" 8 -1/2" Tubing 41.8' RKB to Tb Hn r 3 -1/2" Kill String 9.2 N -80 Butt 2.992 Surf 2792' JEWELRY DETAIL E NO. Depth ID Item LL 0 CIW 4 -1/2" EUE 8rd X Butt Tb . Hanger. 4200' NA Fasdrill Retainer. t4, y ,> 4320' NA Fasdrill Bridge Plu 1 1 9,601 4.0 Baker "FB -1" Pkr. w/ 10' Seal bore ext. & bell guide, w/ "SB" Pkr Plu 1 2 10,068' 3.25 Baker Model "D" Pkr. [Csg Shoe 10,078' 2.75 Otis "X" Nipple, size 2.75 x @9660'DIL g 10,086' 3.00 Bell Guide $ I l a i 3 10,198' 3.25 Baker Model "D" Pkr. V° ° 10 2.625 Otis "Q" Nipple size 2.625 m 10 Mule Shoe B - 1 Brief Details & Info: To date Spudded D -20 on 9/20/69. TD 10 on 10/25/69. Com leted & RR on 11/06/69. .Hole Section MWT: •A pproximate Rotating hrs: 3 o 17 -1/2" to 3050' 9.9 to 10 PPg o 33" 60 hrs o 12 -1/4" to 9 9.8 to 10 ppg 0 13 -3/8" 285 hrs o 8 -I/2" to 10 0 9 -5/8" 51 hrs Filltagged o 7" 16 hrs R on 8/25104 @ 10,040' -4 A 4/29/75 D -27 collided w/ D-20 while drilling 17 -1/2" surface hole. Communication to Inlet Spotted 500sx of G cmt @ 400' 2 in D -27. Possible length of breach in 13 -3/8" is 1488' to 1497'. Penetration in D-20 9 -5/8" @ 1497'. s ` 7/75 WO sqz'd 9 -5/8" csg @ 1497' 4x. Total cmt placed 650 sx. ULL 1 -.. Filitaggedon *' $126188 @ 10,201' -5 PERFORATION DATA Accum Last No Joy on 2- 11,6" tbg thm OO In 11 93 3 WO Zone Top Btm Amt. SPF Perf Date Present Condition In 11 Sqz 9,750' 9,751' 1' 4 10/30/1969 Sqz 75 sx cmt. B -1 9,820' 9,885' 65' 20 6/15/1992 Open f/ Production B -3 9,905' 9,950' 45' 16 6/15/1992 Open f/ Production B -4 9,950' 10,065' 115' 16 6/15/1992 Open f/ Production M -6 B -5 10,070' 10,190' 120' 16 Jul -75 Open f/ Production *� B -6 10,230' 10,260' 30' 4 Jul -75 Open f/ Production k PBTD = 10,430' TD = 10,506' MAX HOLE ANGLE = 21e, @ 2100' D -20 Schematic 3- 29- 07.doc CRW: 3/29/2007 DOLLY VARDEN WELLSLOT DIAGRAM 01/01/10 D -11 D -29RD S/1 D -7RD2 S I D -32 I , D -17RD S/1 D - 28 S/1 s/1 s/I rr 2 —3RD 4 2 —31R 4 S D -9RD D -34 s/1 D -40RD D -1 ES —15RD 1 D -4 '�' D -27 S/I ADPN 1 D -2 5 1 1 r � Sri 1 ' S 1 1 S S/1 6 D -46 D -41 r, D -5RD s/1 D -43RD ES � � 7 D -47 a —42 D -25R D -26RD Leg A-2 Z Leg A -1 NW Corner NE Corner Rig #77 Rig #76 3 0 0 V) 3 21 Producer Dual Gas Well Injector Completion E D -2ARD ° S/1 D -4RD o D -22 S/1 7 a s/I N 's' Z 6 9 s/I D -48 a 12 D -16RD s/I 12 s ° 1 5 D -30 D2 10 6 5 C 10 S I D -12R i 1 1 1 S/1 v, rr a S /; — 8 D -8RD o 4 � D -20 S/1 ° Y 4 2 r o 3 3 2 j D -14RD D -6RD m U Leg B -2 Leg B -1 % (DEDICATED TO SW Corner COMPRESSORS) SE Corner 0 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Suspended Well! Inspedton Report Date Inspected: trapector. V " 0 r [ Operator i a +`- / fj '- I Well Name: Oper- Rep: PTO No.: Oper. Phone: Location Verified? Oper. Email: if verified. How? Onshore / Offshore: b Suspension Date: . Date AOGCC NotHfed: Sundry No.: Type of Inspection Uf y A G... Wellbore Diagram Avall.? �- Well Pressures (pot): Tubing V C u uM Photos Taken? c � IA OA Condlifion at �o ©jj Al i> �� a w L j Wefiheaa: Condition of 1 l!t Q 0 ' - 't Surrounding Surface Location: Follow Up Actions A' to r� Needed: —' Attachments: REVIEWED al(' Insp. SUMV . Z--4 F6B 0WM O suepended Wen Inspection Form:xis Kanyer, Christopher V From: Grimaldi, Louis R (DOA) [lou.grimaldi @alaska.gov] Sent: Saturday, October 02, 2010 12:09 PM To: Greenstein, Larry P Subject: D -20 Pics Attachments: TBU D -20 09 -23 -10 LG b.JPG; TBU D -20 09 -23 -10 LG.JPG Larry, Thanx for the diagram, here are the pix from the Dolly. I did not see any probs with the wells themselves. A few diagram probs that should have been taken care of, speaking of which has the slot diagram for the GPPF been fixed yet and can I get a copy of that? As usual I had a great time with everyone this week and if it wasn't for having to put on and take off that @ #$$ %##@ dry suit a hundred times I would have felt bad about taking pay for it. So I will accept my meager pitance of a check with a smile on my face. Say hi to all and tell them they are still the best hands I know. Lou From: Greenstein, Larry P [mailto:Greensteinlp @chevron.com] Sent: Sat 10/2/2010 11:17 AM To: Grimaldi, Louis R (DOA) Subject: RE: Bruce & Anna suspended well schematics - Can't find Br 40 -42 right now, but I'll keep looking You bet, Lou. Here is the Br 40 -42 schematic. I confirmed these tubulars with the drilling folks and they have decided to change the status of this well from a suspended well to a shut -in gas well. With those open perfs down there, it doesn't meet the current definition of a suspended well. That 10-404 has already been sent to the state, I believe. The inspection is complete, just in case, so your report probably should go in as planned. From what I'm seeing, it appears all the suspended wells we have look to be in good condition. We'll follow up the various inspector visits with our 10 -404 reports here in October. One more thing, if you can, could you send me a copy of the pics you took for the D -20 SWI ?? The operators didn't take any because you had already done so. I'd like them for our paperwork also. Thanks Lou. Larry From: Grimaldi, Louis R (DOA) [mailto:lou.grimaidi @alaska.gov] Sent: Saturday, October 02, 2010 11:04 AM To: Greenstein, Larry P Subject: RE: Bruce & Anna suspended well schematics - Can't find Br 40 -42 right now, but I'll keep looking Larry, Any luck yet, I have to turn my reports in soon. Lou From: Greenstein, Larry P [mailto:Greensteinlp @chevron.com] Sent: Tue 9/28/2010 11:22 AM To: Powell, Dennis A; Grimaldi, Louis R (DOA) Subject: Bruce & Anna suspended well schematics - Can't find Br 40 -42 right now, but I'll keep looking 1 x i 8 Y m r < � f � 1IN► �ww e 7 l y ' tik9 Y si ft WON r At „r Y Awlw .3 Y Ycn, k x gz„ t y µ' Y t AFR l-, J, 3 SR 4 # v 3 r March 31, 2009 Dale Haines Alaska Area Operations Manager Cathy Foerster Commissioner Alaska Oil & Gas Conservation Commission 333 W. 7th Avenue Anchorage, Alaska 99501 Re: Suspended Wells Dear Commissioner Foerster, \ 4of, —O`'1S Union Oil Company of California P.O. Box 196427 Anchorage, AK 99519-6247 Tel 907 263 7951 Fax 907 263 7607 Email Daleah@chevron.com Please find the attached corrections to the suspended and long term shut in well list as provided in your letter dated January 28, 2009. As per our discussion the submitted list needs to be expanded to include additional wells that may not currently be identified on the list provided by the Commission. We also provide the Commission with an annual shut in well report that is sent to Steve McMains. This report was mailed to the Commission on March 30, 2009. At this time I cannot validate that we have provided the Commission with a comprehensive list of all suspended wells so it is our intention to validate the two lists and to review our records to ensure that we have accurately responded to the request. We will therefore endeavor to provide a comprehensive list to the Commission in the next two weeks. Chris Myers will contact Jim Regg to discuss the scheduling inspections of the suspended wells in 2009. If you have any questions about this submittal, please contact myself. Sincerely, Dale Haines Alaska Area Operations Manager Attachment Cc: Tim Brandenburg Chris Myers Dave Cole Union Oil Company of California / A Chevron Company http://www.chevron.com Corrections for the referenced list of suspended and long-term shut-in wells operated by UNOCAL. Well Name API# PTD Current Listed Status Corrected Status Bruce 18742 #40 50-733-20339-00 181-022 Suspended Shut -In SRU 14-15 50-133-10145-01 100-146 Suspended Shut -In SCU 243B-04 50-133-20489-00 199-055 Suspended Shut -In �pT y� ALASKA ®I 7L�.�.l�hD aY7[a►7S CONS 1. RVAT110 COi* DnSS101t r January 28, 2009 CERTIFIED MAIL RETURN RECEIPT REQUESTED 7005 1820 0001 2499 6019 I)alc Maines 11NOCAl, 3800 Centerpoint Dr. Ste 100 Anchorage AK 99503 Re: Notice of Revised Suspended Wells Regulations and Request for Verification of Suspended and Shut -In Well Information Dear Mr. l iaines: SARAH PALIN, GOVERNOR 338 'N. 7th AVENUE. SUITE 100 AN:;HORAGE, ALASKA 99501.3539 PHONE (907) 279-1.433 FAY. (907) 276.75:2 Enclosed are the Alaska Oil and Gas Conservation Commission's revised regulations rcgarding suspended wells (i.e., 20 AAC 25.110). Also enclosed is a list of suspended and long-term shut-in wells operated by 11NOCA1,. For each list, please verify the information for each well and provide any corrections by April 1, 2009. location inspections required under 20 AAC 25.110 should be coordinated with .lim Regi, at 907-793-1236 orj*lni.rcgc;@alaska.gov. P' twit.! h1uv:' _tire O'UPctions !: 2';rrt-n4) Chic notice, --ase _ontac! Tom V_mnd.^r at Q07-791- 1250 or tom.maunder@alaska.gov. Sincerely, Cathy P. Foerster Conirnissioner l'nclosures Operator Suspended anti Slit,t in Wells UNION OIL CO OF CALIFORNIA /Meld Currcai Dale of Permit AI11 Number Well Mince titslluS s(aluS ................. Surl•ace Loc:Minn .................................................... Leasc(s)................. .................. BIRCH HILL 165-001-0 50-133-10029-00-00 BIRCH HILL UNIT 22-25 SUSP 3/7/1988 1836 FNL 1954 FWL Sec 25 T 9 N R 9 W SM FEDA028407 DEEP CREEK 207-123-0 50-231-20031-00-00 HAPPY VALLEY 8-12 SUSP 11/25/2007 2908 FNL 293 FEL Sec 21 T 2S R 13 W SM FEE-CIRI 17 IV /I - s GRANITE PT 196-045-0 50-733-20472-00-00 GRANITE POINT 52 SUSP 8/11/1997 2428 FNL 1298 FWL Sec 13 T ION R 12W SM ADL0018761 196-013-0 50-733-20470-00-00 GRANITE POINT 54 SUSP 4122/2006 2427 FNL 1303 FWL Sec 13 T ION R 12W SM ADL0010761 197-145-0 50-733-20479-00.00 GRANITE POINT 55 SUSP 8/26/1997 2437 FNL 1303 FWL Sec 13 T ION R 12 W SM ADL0374044 167-057-0 50-733-20046-00-00 GRANITE PT ST 11-24 SUSP 9/30/1997 2383 FNL 1368 FWL Sec 13 T ION R 12 W SM ADL0018761 167-023-0 50-733-20016-00-00 GRANITE PT ST 18742 09 SUSP 9/16/1989 834 FNL 676 FEL Sec 12 T ION R 12 W SM ADL0018742 167-042-0 50-733-20032-00-00 GRANITE PT ST 18742 10 SUSP 9/29/1988 1948 FSL 1979 FWL Sec 31 T 11N R 11W SM ADL0018742 178-096-0 50-733-20119-00.00 GRANITE PT ST 18742 31 SUSP 10/7/1988 1945 FSL 1982 FWL Sec 31 T 11 N R 11W SM ADL0018742 179-017-0 50-733-20441-01-00 GRANITE PT ST 18742 34 SUSP 9/20/1991 2012 FSL 1945 FWL Sec 31 T 11 N R 11 W SM ADL0018742 181-022-0 50-733-20339-00-00 GRANITE PT ST 18742 40 SUSP 4121/1982 1948 FSL 1975 FWL Sec 31 T 11 N R 11W SM ADL0018742 195-005-0 50-733-20465-00-00 GRANITE PT ST 18742 52 SUSP 7/9/1995 730 FNL 682 FEL Sec 12 T ION R 12W SM ADL0018742 MCARTHUR RIVER 169.095-0 50-733-20203-00-00 TRADING BAY UNIT D-20 SUSP 1/31/2007 672 FSL 1211 FWL Sec 6 T 8N R 13W SM ADL0018729 173-001-0 50-733-20248-00-00 TRADING BAY UNIT K-17 SUSP 4/20/2002 694 FSL 83 FEL Sec 17 T 9 N R 13W SM AOL0017594 SWANSON RIVER 199-055-0 50-133-20489-00-00 SOLDOTNA CK UNIT 2438-04 SUSP 9/22/1999 2003 FSL 575 FEL Sec 4 T 7N R 9W SM FEDA028997 180-106-0 50-133-20232-01-00 SOLDOTNA CK UNIT 42A-05 SUSP 8/9/2006 1879 FSL 498 FEL Sec 5 T 7N R 9W SM FEDA02.8997 182-199-0 50-133-20363-00-00 SOLDOTNA CK UNIT 42B-05 SUSP 6/21/2006 1823 FSL 572 FEL Sec 5 T 7N R 9W SM FEDA028996 100-146-0 50-133-10145-01-00 SWANSON RIV UNIT 14-15 SUSP 1/28/1997 360 FSL 1680 FEL Sec 16 T 8 N R 9W SM FEDA028406 162-034-0 50-133-10148-00-00 SWANSON RIV UNIT 14-22 SUSP 10/5/1995 660 FSL 660 FWI. Sec 22 T 8 N R 9 W SM FEDA028406 172-007-0 50-133-20237-00-00 SWANSON HIV UNIT 24-33 SUSP 4/1/1993 932 FNL 2089 vWL Sec 4 T 7 N R 9 W SM FED/1028399 162-030-0 50-133-10143-01-00 SWANSON RIV UNIT 41A-15 SI 8/26/1987 615 FNL 715 FEL Sec 15 T 8 N R 9W SM FEDA028384 203-074-0 50-133-20523-00-00 SWANSON RIVER KGSF 3 SUSP 8/2212007 1754 FNL 4030 FEL Sec 27 T 8 N R 9 W SM FEDA028406 _ s 11'ednesdnr, Jaintur .1,14,2009 p c� 1T Z Operator Suspended and Shut In Wells UNION OIL CO OF CALIFORNIA Field Current Date of Permit API Number Well Name Status Status Surface Location .................................................... Lease(s)................................... TRADING BAY 190-041-0 50-733-20302-01-00 TRADING BAY STA -20120 SUSP 4/23/1990 1604 f:SL 559 FCL Sec 4 T 9 N R 13 W SM ADI -0018731 �. o N o 108.1 Iq- // 11'ednesdaY, Janitaq 14, 2009 20 f+AC 25.1 10. Suspended wells (a) if i[HOwCd under 20 AAC 25..10. the C0111171iSSion will, upo:-, ahhl:cation by GIC operator under (b) of this section, approve the suspension of a well is (1) the well (A) encounters hydrocarbons of sufficient quality and quantity to in�Jicate that the well is capable of producing in paying quantities, as reasonably demonstrated by well tests or interpretive fonllation evaluation data; for purposes of this paragraph, "paying quantities" means quantities sufficient to yield a return in excess of operating costs; (H) is a candidate for redrilling; (C) has potential value as a service well; or (D) is located on a pad or platform with active producing or service -ells; and (?) the operator }usti{ics to the commission's satisfaction why the well shoule not be abandoned, and, if the well is not completed, why the well should not be completed; sufficient reasons include the (A) unavailability of surface production or transportation facilities; (t3) imprudence of security maintenance of a completed well in a sht:t-in status; (C) need for pool delineation and evaluation to determine the prudence of pool development. (b) An Application for Sundry Approvals (Form 10-403) must be submitted :o and approved by the commission before plugging operations are begun in a well for which suspensio r is proposed, except that oral approval may be obtained from the commission if it is followed within three days by the submission of an Application for Sundry Approvals for final approval by the commission. Approval will be conditioned as necessary to protect freshwater and hydrocarbon resources. An Application for Sundry Approvals must include (1) the reason for suspending the well and information showing that the applicable criteria for suspension under (a) of this section have been met; and (?) it statement of proposed work, including (A) information on abnon-nally geo-pressured strata; (13) the manner of placement, kind, size, and location, by measured depth, of existing and proposed plugs; (C) plans for cementing, shooting, testing, and removing casing; (ll) il'thc /\171)11c„tio1l for Sundry Approvals is submitted after bcgli-ning work, the nanic of the representative of the commission who provided oral approva , and the date: of the approval; and (E) other information pertinent to suspension of the well. (c) At the operator's request accompanying the submission, info^nation subrr.ittcd to show that the applicable criteria for well suspension under (a) of this section have been met will be kept confidential (1) for the period specified under AS ') 1.05.035 (c), if the information is described in 20 AAC 25.071 (jg) ; or (2) for the time that the infonmation has value as a trade secret, if fAc infonnaticn is not described in 20 AAC 25.07] b but is determined by the commission: to constitute a trade secret under AS 45.50.940 . (d) A well approved for suspension must be plugged in accordance with the requirements of 20 AAC 25.112, except that the requirements of 20 AAC 25.112(d) do not apply if (1) a wellhead is installed or the well is capped with a mechanical device to seal the opening; and (2) a bridge plug capped with 50 feet of cement or a continuous cement plug extending 200 feet within the interior casing string is placed at or above 300 feet below the surface; the commission will waive the requirement of this paragraph for a development well drilled from a pad or platform, if the commission determines that the level of activity on the pad or platfonn assures adequate surveillance of that development well. (e) Until a suspended well has been abandoned or re-entered, the operator shall rnaintain the integrity of the location, provide the commission with a well status report every five years, and clear the location in accordance with 20 AAC 25-112W (2) or (b) or with 20 AAC 25._172(c) (2) or (d), as applicable. History: Eff. 4/2/86, Register 97; am 11/7/99, Register 152 Authority: AS 31.05.030 �S *� ALASKA O SARAH PALIN, GOVERNOR ALASKA OIL AND GAS 333 W 7th AVENUE, SUITE 100 CONSERQAIRON COM USSION ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAx (907) 276.7542 January 28, 2009 CERTIFIED MAIL RETURN RECEIPT REQUESTED 7005 1820 0001 2499 6019 Dale Haines UNOCAL 3 800 Centerpoint Dr. Ste 100 Anchorage AK 99503 Re: Notice of Revised Suspended Wells Regulations and Request for Verification of Suspended and Shut -In Well Information Dear Mr. Haines: SCANNED f" C Enclosed are the Alaska Oil and Gas Conservation Commission's revised regulations regarding suspended wells (i.e., 20 AAC 25.110). Also enclosed is a list of suspended and long-term shut-in wells operated by UNOCAL. For each list, please verify the information for each well and provide any corrections by April 1, 2009. Location inspections required under 20 AAC 25.110 should be coordinated with Jim Regg at 907-793-1236 or jim.regg@alaska.gov. If you have any questions regarding this notice, please contact Toni Maunder at 907-793- 1250 or tom.maunder@alaska.gov. Sincerely, 01 /1/_2�je� Cathy P. Foerster Commissioner Enclosures ■ Complete items 1, 2, and 3. Also complete item 4 if Restricted Delivery is desired. ■ Print your name and address on the reverse so that we can return the card to you. ■ Attach this card to the back of the mailpiece, or on the front if space permits. 1. Article Addressed to Dale Haines UNOCAL 3800 Centerpoint Dr. Ste 100 ! Anchorage AK 99503 4 A. tgnature X 9 �, Cf�A nt �V! 13ddresse 9 - "Received by( Printed Name) C. a of FIi ry D. Is delivery address different from item 1? ❑ Y s If YES, enter delivery address below: ❑ No S ice Type rtified Mail ❑ Express Mail ❑ Registered Cq*eturn Receipt for Merchandise ❑ Insured Mail ❑ C.O.D. 4. Restricted Delivery? (Extra Fee) ❑ Yes 2. Article Number (Transfer from service label) 7005 1820 0001 2499 6 019 PS Form 3811, February 2004 Domestic Return Receipt 102595-02-M-1540 I Postal o, CERTIFIED MAIL,. RECEIPT o(Domestic Mail . .- Er A�R�GE t *163 tr' U SLE fU gPS POST r -i Postage Certified Fee41. $ $0.59 9 ® ED 2.�{� F N ® Return Receipt Fee (Endorsement Required) $2.20 S ►{ O� ?. C3 rU Restricted Delivery Fee (Endorsement Required) $0.00 r, '$jC r FAK � LocC Total Postage 8 $5.49 011281 Dale Haines C3 sent To UNOCAL r Sliest, Apt. filo.; or PO Box No. 3800 Centerpoint Dr. Ste 100 city sie, ziR« Anchorage AK 99503 ■ Complete items 1, 2, and 3. Also complete item 4 if Restricted Delivery is desired. ■ Print your name and address on the reverse so that we can return the card to you. ■ Attach this card to the back of the mailpiece, or on the front if space permits. 1. Article Addressed to Dale Haines UNOCAL 3800 Centerpoint Dr. Ste 100 ! Anchorage AK 99503 4 A. tgnature X 9 �, Cf�A nt �V! 13ddresse 9 - "Received by( Printed Name) C. a of FIi ry D. Is delivery address different from item 1? ❑ Y s If YES, enter delivery address below: ❑ No S ice Type rtified Mail ❑ Express Mail ❑ Registered Cq*eturn Receipt for Merchandise ❑ Insured Mail ❑ C.O.D. 4. Restricted Delivery? (Extra Fee) ❑ Yes 2. Article Number (Transfer from service label) 7005 1820 0001 2499 6 019 PS Form 3811, February 2004 Domestic Return Receipt 102595-02-M-1540 I Operator Suspended and Shut In Wells UNION OIL CO OF CALIFORNIA Field Current Date of Permit API Number Well Name Status Status Surface Location .................................................... Lease(s)................................... BIRCH HILL 165-001-0 50-133-10029-00-00 BIRCH HILL UNIT 22-25 SUSP 3/7/1988 1836 FNL 1954 FWL Sec 25 T 9 N R 9 W SM FEDA028407 DEEP CREEK 207-123-0 50-231-20031-00-00 HAPPY VALLEY B-12 SUSP 11/25/2007 2908 FNL 293 FEL Sec 21 T 2S R 13W SM FEE-CIRI GRANITE PT 196-045-0 50-733-20472-00-00 GRANITE POINT 52 SUSP 8/11/1997 2428 FNL 1298 FWL Sec 13 T ION R 12W SM ADL0018761 196-013-0 50-733-20470-00-00 GRANITE POINT 54 SUSP 4/22/2006 2427 FNL 1303 FWL Sec 13 T ION R 12 W SM ADL0018761 197-145-0 50-733-20479-00-00 GRANITE POINT 55 SUSP 8/26/1997 2437 FNL 1303 FWL Sec 13 T ION R 12W SM ADL0374044 167-057-0 50-733-20046-00-00 GRANITE PT ST 11-24 SUSP 9/30/1997 2383 FNL 1368 FWL Sec 13 T ION R 12 W SM ADL0018761 167-023-0 50-733-20018-00-00 GRANITE PT ST 18742 09 SUSP 9/16/1989 834 FNL 676 FEL Sec 12 T ION R 12 W SM ADL0018742 167-042-0 50-733-20032-00-00 GRANITE PT ST 18742 10 SUSP 9/29/1988 1948 FSL 1979 FWL' Sec 31 T 11 N R 11 W SM ADL0018742 178-096-0 50-733-20119-00-00 GRANITE PT ST 18742 31 SUSP 10/7/1988 1945 FSL 1982 FWL Sec 31 T 11 N R 11 W SM ADL0018742 179-017-0 50-733-20441-01-00 GRANITE PT ST 18742 34 SUSP 9/20/1991 2012 FSL 1945 FWL Sec 31 T 11 N R 11 W SM ADL0018742 181-022-0 50-733-20339-00-00 GRANITE PT ST 18742 40 SUSP 4/21/1982 1948 FSL 1975 FWL Sec 31 T 11 N R 11 W SM ADL0018742 195-005-0 50-733-20465-00-00 GRANITE PT ST 18742 52 SUSP 7/9/1995 730 FNL 682 FEL Sec 12 T ION R 12 W SM ADL0018742 MCARTHUR RIVER 169-095-0 50-733-20203-00-00 TRADING BAY UNIT D-20 SUSP 1/31/2007 672 FSL 1211 FWL Sec 6 T 8 N R 13 W SM ADL0018729 173-001-0 50-733-20248-00-00 TRADING BAY UNIT K-17 SUSP 4/20/2002 694 FSL 83 FEL Sec 17 T 9 N R 13W SM ADL0017594 SWANSON RIVER 199-055-0 50-133-20489-00-00 SOLDOTNA CK UNIT 24313-04 SUSP 9/22/1999 2003 FSL 575 FEL Sec 4 T 7 N R 9 W SM FEDA028997 180-106-0 50-133-20232-01-00 SOLDOTNA CK UNIT 42A-05 SUSP 8/9/2006 1879 FSL 498 FEL Sec 5 T 7 N R 9 W SM FEDA028997 182-199-0 50-133-20363-00-00 SOLDOTNA CK UNIT 4213-05 SUSP 6/21/2006 1823 FSL 572 FEL Sec 5 T 7 N R 9 W SM FEDA028996 100-146-0 50-133-10145-01-00 SWANSON RIV UNIT 14-15 SUSP 1/28/1997 360 FSL 1680 FEL Sec 16 T 8 N R 9 W SM FEDA028406 162-034-0 50-133-10148-00-00 SWANSON RIV UNIT 14-22 SUSP 10/5/1995 660 FSL 660 FWL Sec 22 T 8 N R 9 W SM FEDA028406 172-007-0 50-133-20237-00-00 SWANSON RIV UNIT 24-33 SUSP 4/1/1993 932 FNL 2089 FWL Sec 4 T 7 N R 9 W SM FEDA028399 162-030-0 50-133-10143-01-00 SWANSON RIV UNIT 41A-15 SI 8/26/1987 615 FNL 715 FEL Sec 15 T 8 N R 9 W SM FEDA028384 203-074-0 50-133-20523-00-00 SWANSON RIVER KGSF 3 SUSP 8/22/2007 1754 FNL 4030 FEL Sec 27 T 8 N R 9 W SM FEDA028406 Wednesday, January 14, 2009 Operator Suspended and Shut In Wells UNION OIL CO OF CALIFORNIA Field Current Date of Permit API Number Well Name Status Status Surface Location .................................................... Lease(s)................................... TRADING BAY 190-041-0 50-733-20302-01-00 TRADING BAY ST A-20RD SUSP 4/23/1990 1604 FSL 559 FEL Sec 4 T 9 N R 13 W SM ADL0018731 Wednesday, January 14, 2009 s • Chevron Francisco Castro Chevron North America Exploration and Production Technical Assistant 909 W. 9th Avenue Anchorage, AK 99501 Tele: 907 263 7889 Fax: 907 263 7828 E-mail: fcbn@chevron.com December 4, 2007 To: AOGCC Howard Okland 333 W. 7th Ave. Ste#100 Anchorage, AK 99501 PERMIT # API NUMBER WELL LOG TYPE SCALE LOG DATE. INTERVAL RUN L000ED # B- LINE FILM CD NOTES - LAS PDS; DLIS COMPLETION - RECORD 4.5" POWERJET 21-Feb- 167-080 507332006801 TBU D-1 OMEGA 5 SPF 5" 07 9000 - 11448 1 1 1 1 PDS ULTRA SONIC IMAGER CORROSION AND 15-Jan- 169-095 507332020300 TBU D-20 CEMENT 5" 07 169 - 9456 1 1 1 1 PDS lTo~ ..~~ 5~ ~ tS ~ ~/b >~f~NNE®DEC ~ 1 zoo? ~:~ Please acknowledge receipt by sianina and returning one copy of this transmittal or FAX to 907 263 7828. . - - - ?4 Received By;~ Date: (/. _ STATE OF ALASKA . . ALA-'OILANDGASCONSERVATIONCOM ION APR 17 Z007 WELL COMPLETION OR RECOMPLETION REPORT AND LOG RECEIVED --_ n .. 1a. Well Status: OilD GasD Plugged D Abandoned D Suspended 0 1b. Well cß~Ka uil 01. Uti;) UUIli>. vUlIlIIlSSI "AA'''''''' ""'" "", Development 0 ~D GINJD WINJD WDSPL D WAGD OtherD No. of Completions:_ ' Service D Stratigraphic TestD 2. Operator Name: 5. Date Compo Susp 12. Permit to Drill Number: ~ . Union Oil Company of California Aband.: 1/31/2007 /69-95 /6 ~t?9.>o :2.. 'N# 3. Address: ~~e Spudded: f!/9'¿" 13. API Number: C607-G g. V l-þ l-¿// ~ N/A - Not a new well {".- P.O. Box 196247, Anchorage, AK 99519 50-733-20203-00 J/! ì.-(¡ '( 4a. Location of Well (Governmental Section): 7. Date TO Reached: I ¡,b·M 14. Well Name and Number: Surface: 672.1'N, 1211.1'E from SW corner (Sec6-T8N-R13W) SI'f NIA - Not a new well Dolly Varden D-20 Top of Productive Horizon: ZO~ ~A'¿/c:::i?~S";rw¿ ~¿, 1?~ 8. KB (ft above MSL): 106' 15. Field/Pool(s): 1\1//\ Net a R8'!\I-Well "e/3 ~ ,SH Ground (ft MSL): nla McArthur River I Hemlock Oil Pool Total Depth: /S"",:r/fL,J.,,2/~:S /:Jl-/L (J'C~", "-/f/V,,e/~ 9. Plug Back Depth(MD+ TVD): . .s. . 4040' MD 13554' TVD 4b. Location of Well (State Base Plane Coordinates, NAD 27): Zone- .; 10. Total Depth (MD + TVD): 16. Property Designation: Surface: x- 208,375 y- 2,490,836 10,506' MD 110,028' TVD Dolly Varden Platform TPI: x-~&U> y-~~9~,;2?' Zone-~ 11. SSSV Depth (MD + TVD): 17. Land Use Permit: Total Depth: x--,O~ ~'1 y-.,.'l~~'.§.. ~¿'.J Zone-'; NIA ADL 18729 18. Directional Survey: Yes 0 No D 19. Water Depth, if Offshore: 20. Thickness of Permafrost (TVD): (Submit electronic and printed information per 20 MC 25.050) NIA (ft MSL) NIA 21. Logs Obtained (List all logs here and submit electronic and printed information per 20 MC 25.071): NIA - Not a new well 22. CASING, LINER AND CEMENTING RECORD WT. PER SETTING DEPTH MD SETTING DEPTH TVD AMOUNT CASING FT. GRADE TOP BOTTOM TOP BOTTOM HOLE SIZE CEMENTING RECORD PULLED 13-3/8" 61 K-55 Surf 3006' Surf 2799' 17-1/2" 2500 Sx Total 9-518 " 40 N-80 Surf 4390' Surf 3816' 12-1/4" 43.5 N-80 4390' 6156 3816' 5199' 12-1/4" 1000 Sx th ru Divert valve 47 N80 SR~ 6156' 9674' 5199' 7932' 12-1/4" 1700 Sxs 7" 29 N-80 9463' 10480' 7270' 8565' 8-1/2' 375 Sxs 23. Open to production or injection? YesD N00 If Yes, list each 24. TUBING RECORD interval open (MD+ TVD of Top & Bottom; Perforation Size and Number): SIZE DEPTH SET (MD) PACKER SET (MD) 3-1/2" Kill String 2792' na ~MA'f () 7 Z007 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED 4320' - 4200' 64 bbls cement 4040' - 4200' cement above fastdrill retainer 26. o- w '.M·~<"'" ,. ............~'Ir........~~.:,'(;':' PRODUCTION TEST Date First Production: Method of Operation (Flowing, gas lift, etc.): NIA - not a new well N/A - not a new well Date of Test: Hours Tested: Production for Oil-Bbl: Gas-MCF: Water-Bbl: Choke Size: GaS-Oil Ratio: NIA - not a new WE Test Period -+ Flow Tubing Casing Press: Calculated Oil-Bbl: Gas-MCF: Water-Bbl: Oil Gravity - API (corr): Press. 24-Hour Rate ... 27. CORE DATA Conventional Core(s) Acquired? Yes D NoD Sidewall Cores Acquired? Yes D NoD If Yes to either question, list formations and intervals cored (MD+ TVD of top and bottom of each), and summarize lithology and presence of oil, gas or water (submit separate sheets with this form, if needed). Submit detailed descriptions, core chips; photographs and laboratory analytical results per 20 MC 25.071. NIA - not a new well ~ "-, ", .~.._~,. .. . 'j; _.' , . , .~ j /-jjb; f RBDMS 8Ft APt! 2 5 2007 4 ~~"J Form 10-407 Revised 2/2007 ONTINUED ON REVERSE Á'-\ on 7 ORIGINAt ( ì- '-1 (; · 28. GEOLOGIC MARKERS (List all formations and markers encountered): NAME MD TVD 29. FORMATION TESTS Permafrost - Top Permafrost - Base Well tested? 0 Yes No If yes, list intervals and formations tested, briefly summarizing test results. Attach separate sheets to this form, if needed, and submit detailed test information per 20 MC 25.071. N/A - not a new well N/A - not a new well. Formation at total depth: 30. List of Attachments: Wellbore Schematic, Operational Summary 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Steve Tyler - 263-7649 Title: Drilling Manager Signature: Phone: 907-263-7600 Date: 3/29/2007 5JlJþ(2..' i4 30(,- <31"¡' INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Submit a well schematic diagram with each 1 0-407 well completion report and 1 0-404 well sundry report when the downhole well design is changed. Item 1a: Classification of Service wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 4b: TPI (Top of Producing Interval). Item 8: The Kelly Bushing and Ground Level elevations in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). Item 20: Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 28. Item 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, or Other (explain). Item 27: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Submit detailed description and analytical laboratory information required by 20 MC 25.071. Item 29: Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 MC 25.071. Form 10-407 Revised 2/2007 RKB to TBG Head'" 41.8' PBTD'" 10,430' TD'" 10,506' MAX HOLE ANGLE'" 21", @ 2100' Wt Grade 61 K-55 Seal Lock 12.515 40 N-80 Butt 8.835 43.5 8.755 43.5 N-80 8.755 9-5/8" Prod Csg Butt 47 S-95 8.681 AR-95 Seal Lock 7" Liner 29 N-80 X-Line 6.185 Tubill 3-1/2" Surf Dtm 400' 3006' 12-114" 9463' 10,480" NO. De in o 4200' 4320' 9,601 10,068' 10,078' 10,086' 10,198' 10,206' 10,212' 1 2 3 B-1 S udded 0-20 on 9/20/69. TD -Hole Section MWT: o 17-1/2" to o 12-1/4" to o 8-112" to 3050' 9,748' 10,506 m NA NA 4.0 3.25 2.75 3.00 3.25 2.625 C1W4-1/2"EUE8rdX ButtTb .Han er Fasdril1 Retainer. FasdrilJ Bnd e Plu Baker "FB-I" Pkr. wi 10' Seal bore ex!. & ben tride. wi "SB" Pkr Plug Baker Model "0" Pkr. Otis "X" Ni Ie, size 2.75 Ben Guide Baker Model "D" Pkr. Otis "Q" Ni Ie, size 2.625 Mule Shoe o o o 4/29/75 D-27 collided wi D-20 whì1e drilling 17-1/2" surface hole. Communication to Inlet Spotted 500s)(. of G cmt@400' in D·27. Possible length of breach in 13-3/8" is 1488' to 1497'. Penetration in D-20 9-5/8" @ 1497' 7/75 WO sqz'd 9-5/8" 1497' 4x. Total emt placed 650 sx. D-20 Proposed Wellbore Secure 12-06.doc Present Condition Sqz 75 ax em!. Open fl Production Open f/ Production fl Production Open fl Production Open fl Production Primary Job Type Workover Jobs Primary Job Type Workover Daily Operations 12/6/200600:00 -12/7/2006 00:00 Operations Summary RU slickline. RIH with 2.72" GR, set down at 8881' RKB. POOH. RIH with 2.5" GR and set down 8876' RKB, spudded to 8878' RKB. POOH. RIH with 2.25" GR and set down at 8876' RKB. Sticky. POOH. RIH with 2.5" dummy gun to 8878' RV Fluid level at 965'. POOH. RIH wI 1-1/4" templpressure tool and log from surface to 3000'. RD slickline. 12/10/200600:00 -12/11/2006 00:00 Operations Summary Mobe 12/11/200600:00 -12/12/2006 00:00 Operations Summary Mobe 12/12/200600:00 - 12/1312006 00:00 Operations Summary Mobe 12/13/200600:00 -12/14/2006 00:00 Operations Summary Mobe 12/14/200600:00 ·12/15/2006 00:00 Operations Summary Mobe 12/15/200600:00 - 12/16/2006 00:00 Operations Summary Mobe 12/16/200600:00 - 12/17/2006 00:00 Operations Summary Mobe 12/17/200600:00·12/18/200600:00 Operations Summary Mobe 12/18/200600:00 -12/19/2006 00:00 Operations Summary Mobe 12/19/200600:00 -12/20/2006 00:00 Operations Summary Mobe 12/20/200600:00 -12/21/2006 00:00 Operations Summary Mobe 12/21/200600:00 - 12/22/2006 00:00 Operations Summary Mobe 12/22/200600:00 -12/23/2006 00:00 Operations Summary Mobe 12/23/200600:00 -12/24/2006 00:00 Operations Summary Mobe 12/24/200600:00 -12/25/2006 00:00 Operations Summary Mobe 12/25/200600:00 -12/26/2006 00:00 Operations Summary Mobe 12/26/200600:00 - 12/27/2006 00:00 Operations Summary Mobe Daily Operations 12127/200600:00 -12/28/2006 00:00 Operations Summary Mobe 12128/200600:00 -12/29/2006 00:00 Operations Summary Prep well. PJSM Mobe rig. Attempt bullheading on tbg, note pressure increase on 7" x 9-5/8" casing. Continue to bull head and after 100 bbls, the pressures on the 7"x9-5/8" built erratically. Attempt to kill well using drillers method. Unable to control pressures.. Bled off well and shut down and monitor pressures. RIH slickline and 2.72" gauge ring. No fluid level noted on trip in hole. RIH to EOT at 9640'. POOH and RD slickline. 12/29/200600:00 -12/30/2006 00:00 Operations Summary RU wireline. RIH with wireline with 1-13/16"x 6 ft tbg punc. Punch tbg one full joint above packer from 9583'-9589'. POOH with all shots fired. RD eline. RU to circ through and choke I kill well. Pump FIW in tbg while monitoring well pressures. Continue to circ until returns are clean. Zero press on tubing and casing. RU to bullhead into 7" x 9-5/8". Mixing and building kill mud volume. 12130/200600:00 -12131/2006 00:00 Operations Summary PJSM. Bullhead FIW down 7"x9-5/8" annulus. Pump until pressure is at 800 psi. Shut in well and monitor. Bled gas from 7"x9-5/8". RU to bullhead into 9-5/8" x 13-3/8". Pump FIW until pressure is 800 psi. Monitor well. Pressure dropped to 200 psi in 40 min. Continue to pressure up and bleed down. Bullhead into 7" x 9-518 annulus. Pressure up to 1200 psi and shut in. Monitor and see pressures drop to 140 psi. Bleed down to 75 psi. Built up to 135 psi on it's own and stabilized. 12/31/200600:00 - 1/1/2007 00:00 Operations Summary PTSM. Continue monitoring pressures. Plumb lines. Mobing. 1/1/2007 00:00 - 1/212007 00:00 Operations Summary PTSM. Pump down tubing to circulate fluids. Remove landing joint and install BPV. Test control lines, and ND flowlines and ND tree. PJSM for NU BOP. 1/21200700:00 - 1/3/2007 00:00 Operations Summary Install 7" rams and function test BOPs. MU 7" test joint and 3-1/2" test joint. Shell test stack, 250 low and 3000 high, OK. Test BOPs. 1/3/200700:00 - 1/4/2007 00:00 Operations Summary Remove TWC, and fill hole. MU test joints and test rams. Run mask up drill. Fill hole for fluid loss (10 BPH). MU landing joint. Pull BPV, install landing joint. CBU taking returns to well clean tank. Attempt to pull hanger. 1/4/2007 00:00 - 1/5/2007 00:00 Operations Summary Pulled hanger to floor. LD landing joint. POOH with 3-1/2" tbg wI 1/4" SS control line. Shen SSSV cleared the 7" casing, well went on vacuum. 64 bbls to fill. Static losses at 18-19 BPH. MU TIW valve and monitor well. Pump 40 bbls of FIW as lead with 60 bbl sized salt pillwith 79 bbl tail. Taking returns to well clean tank. POOH LD and standing back tbg. Circulate hole. Static losses at 3 BPH. POOH LD tubing. Taking NORM reading. Continue monitoring pressures. 1/5/200700:00 - 1/6/2007 00:00 Operations Summary Finish POOH with tbg. LD GLM. NORM readings are noted. Scale on OD of tbg. Monitor and play with pressures. 1/6/200700:00 -1/7/2007 00:00 Operations Summary PTSM. RU Hawk Jaw. MU wear ring XO from 4-1/2" to 3-1/2". RIH and set ring. Release ring and PU 2 feet on 3-1/2". Function test Koomey. LD wear ring puller and XO. PU BOT SV Packer plug and inspect shear pins. PU RIH with packer plug on 3-1/2" DP. 1/7/200700:00 - 1/8/2007 00:00 Operations Summary Cont to PU 3-1/2" DP and tag up at 9485'. Attempt to wash past. No joy. POOH with DP. Missing Baker SB Packer plug. MU Bker 5-3/4" fishing assly, PU jars and drill collars. RIH with 3-1/2" DP. 1/8/200700:00 -1/9/2007 00:00 Operations Summary PU kelly and torque up. MU test hose. RIH to fish at 9485'. POOH with BHA and fishing assymb. Recovered Packer plug. Monitor well bore. PU 2-7/8" tbg cement stinger, and RIH with 3-1/2" DP to 9606'. ~c 6 Chevro - Alaska SWW Daily Op rations Summary Well Name D-20 Field Name MCARTHUR API/UWI 507332020300 Lease/Senal ADL0018729 O"g KB Elev (ltKB) Water Depth (It) Daily Operations 1/9/200700:00 - 1/10/2007 00:00 Operations Summary Mix sand pill. Pump 28.5 bbl pill chased with 46 bbl. POOH. RIH to tag top of sand. Found no sand. Try again. No Joy. Pump high vis sweep. POOH. PU MU test joint. Pull wear ring and set test plug. 1/10/200700:00 -1/11/2007 00:00 Operations Summary Test BOPs. RIH with packer plug. Tag and latch into packer at 9606. Saw pressure drop. POOH to 9452' and pour 18 sxs dry sand. POOH with setting tool. 1/11/200700:00 -1/12/2007 00:00 Operations Summary POOH with DP. PU drill collars, 7" RTTS packer. RIH and set at 1641'. Pressure test 7" scab liner to 1000 psi. POOH with RTTS to inspect. Cleaned and RIH and set at 1641 '. Test 7" scab liner to 1000 psi. Release from RTTS and circulate. POOH with DP and RTTS running tool. Pull wear ring ND choke. PU BOP stack and riser. Remove DSA and DCB spool. 1/12/200700:00 -1/13/2007 00:00 Operations Summary Continue ND spools. Secure csg hanger to 7". NU BOPE test same. RIH engage RTTS. Release & POOH wI same. LD RTTS. PUMU mechanical 7" csg cutter. RIH wI csg cutter. Cut 7" @ 1667'. CBU. POOH found two cutter tips broke. 1/13/200700:00 -1/14/2007 00:00 Operations Summary LD 7" csg cutter. RIH wI spear. Engage 7" csg. POOH LD 7". RIH wI spear. Engage tension hngr @ 1667'. Worked tool string to get fish to release. 1/14/200700:00 -1/15/2007 00:00 Operations Summary Continue to work fish. POOH LD tension hngr pkr. PUMU csg scrapper & Stab sub assy. RIH worked tools to 4305'. No further progress. POOH. LD stab subs. RIH wI tandom csg scrapper assy. Worked through tite spot @ 4389'. 1/15/200700:00 -1/16/2007 00:00 Operations Summary Continue RI wI tandom scrapper assy. Work tight spot at 4275' to 4289'. RIH to TOL @ 9463'. CBU sweep. POOH work tight spot 4305' to 4290'. Cont POOH. LD BHA. RU Eline. RIH wI USIT Logging tool to TOL @ 9463'. Log up to 200'. 1/16/200700:00 - 1/17/2007 00:00 Operations Summary PUMU RBP and RTTS pkrlBP assy. RIH to 1463'. Set RTTS. Attempt to unset pkr to move down hole. RTTS not funtioning correctly. POOH. Found service break loose on pkr. Conduct BOPE test. PUMU 9-5/8" Champ pkr. RIH to 1460'. Set pkr. Test PC above pkr to 1500 psi for 30 min. 1/17/200700:00 - 1/18/2007 00:00 Operations Summary test packer at 1460'. Good test. Set packer at 1512' and test packer. Small leak. Space out for test #3. Set packer element at 1531'. Leaking again. Attempt to pump, no joy. Reset packer at 4208'. Pressure up, didn't pass test, leaking. Repeat test #1 and pressure up 9-5/8" x 3-1/2" DP annulus. Good test. RIH and set center pkr at 1512'. Pump down DP and establish returns on annulus. Unseat Packer and POOH. Circ across top of hole. No static losses. RIH with mill BHA on 3-1/2" DP while filling pipe to 4353' (bit depth). Pick up Kelly and ROT string mill. Seeing torque. Checking fluids, no dirty returns. 1/18/200700:00 -1/19/2007 00:00 Operations Summary PU 3-1/2" DP. RIH with string mill to 4385'. No obstructions. Circulate bottoms up to clean. POOH with 3-1/2" DP. SB DC's. LD BHA, note string mill had very little wear. Recovered full basket of metal cuttings. PU BHA #14wl HES 9-518" bridge plug and setting tool. RIH to set packer at 4320'. Confirm set. TOH with setting tool. PUHES Fast Drill Retainer (BHA #15). RIH and set at 4200'. Confirm set. Sting into retainer and attempt to establish circulation rates, pumped with no returns. Pulled out of retainer and circulated above with no problems. Stab back into retainer and pumped again with no returns. Continued to work at pumping and finally established partial returns to surface (final attempt pumped 21 bbls with 12 bbls returns). 1/19/200700:00 - 1/20/2007 00:00 Operations Summary Continue to attempt to establish circulation. Inconsistant results. . Established injection rates into formation. Stab back into retainer for cementing. Mix and pump 64 bbls cement. Final squeeze pressure of 1700 psi. POOH with well on good u tube. RU to circulate. Circ BU. No static losses. POOH SB DP. 1/20/200700:00 - 1/21/2007 00:00 Operations Summary Cont to POOH with DP and Retainer setting tool. LD same. Stage pressure and squeeze. Dress 9-5/8" bridge plug and setting tool. PU BHA RIH to 1531'. Circ and establish balance. Batch up 15.8# LXT slurry. Circ cement to EOT. POOH slow with DP. Calc TOC at 687'. LD tools. Stage up pressure and establish squeeze pressures. Squeeze at 1750, 2000, 2250, 2500 psi. . i I I Daily Operations 1/21/200700:00 - 1/22/2007 00:00 Operations Summary Monitor pressure. PU BHA. TIH to 596' with DP. Kelly up and wash to 750' and tag. Drill cmt down to 1100'. Circulate BU to pooh. 1/22/200700:00 -1/23/2007 00:00 Operations Summary Finish circulating well. Blow donw kelly and stand back. RIH and tag 1100'. Kelly up and wash down to 1100'. Drill cment from 1100' - 1134'. Blow down kelly and stand back. POOh and secure well. Hold facility wide Safety Stand Down with production and drilling crews. LD DP. Stand back BHA. MU PDC Bit. RIH with BHA. Scope change. POOH and Stand back BHA. Prepare to test csg. Pressure test 9-5/8" casing to 1124' cement top to 1500 psi. Good test. ND BOP. Break stack at riser top, and stand back. Break 7" csg spool and pull to rig floor. NU BOPs. 1/23/200700:00 -1/24/2007 00:00 Operations Summary NU BOPE and test DCB to 250/2500. Function test BOPE 250/2500. PU BHA, RIH tag cement. 1/24/200700:00 - 1/25/2007 00:00 Operations Summary Tag cement at 1133'. Drill cement to 1531', tag bridge plug. Drill on bridge plug. Appears to be walking down hole. Circ hole clean. Blow kelly dwn. Stand back. POOH and lay down DP. TIH and tag on firm cement at 3943'. 1/25/200700:00 - 1/26/2007 00:00 Operations Summary PTSM. Drill cement and bridge plug pieces @3,943'. POOH and lay down 43 jts. 3-1/2" DP. MU fishing assembly. TIH and tag fish at 2390'. Work over fish. POOH with fish. Break out and lay down fishing assembly (fish -3-1/2" DP box). POOH laying down 3-112" DP. 1/26/200700:00 -1/27/2007 00:00 Operations Summary POOH and lay down DP. TIH with DP. Tag at 4040'. Kelly up and bread circ. Circulate and treat mud. Displace hole with FIW. Circulated with 365 bbls of FIW. Good clean returns. PJSM, break off and blow down kelly, set back, and POH to PU RTTS. 1/27/200700:00 -1/28/2007 00:00 Operations Summary PU RTTS and start in hole. snagged wear ring. PU champ packer and RIH. Set packer at 1496'. No joy on pressure test. Run down to 1534' and attempt to test again. Same results. Pull up to 1460', and pressure up annulus to 1500 psi. Held for 15 min. POOH and LD camp packer. PU RTTS. RIH and set at 1534'. Pressured up. RIH and reset RTTS at various depths to attempt to isolate leak in 9-5/8". Set at 2013' - good test. Set at 1685'- good test. Set at 1609' - failed test. Set at 1650' - failed test. Indication leak in csg between 1650' and 1685'. POOH and lay down RTTS. 1/28/200700:00 -1/29/2007 00:00 Operations Summary PTSM. POOH with RTTS tool. TIH with 3-1/2" DP to 4015'Tag at 4040'. Pump 1 drum corrosion inhibitor. Blow down kelly and POOH and LD 45 jts 3-1/2" DP. Trip back in hole and circ pill just off bottom. PJSM. TOH and LD 20 stands of 3-1/2" DP. POOH and lay down remainder of 3-1/2" DP. 1/29/200700:00 - 1/30/2007 00:00 Operations Summary LD remaining tubulars. Pull wear bushing, layout kelly. RU tongs. RIH w/3-1/2" kill string. Land at 2792' RKB. ND BOPE. Remove rams and ND BOP. ND riser. 1/30/200700:00 - 1/31/2007 00:00 Operations Summary LD riser. NU tree. Test tubing hanger to 250psi (low) and 5000psi (high). Demob. . ~1f~1fŒ (ID~ ~~~~æ~ . A.I.A.~1iA. OIL AND GAS CONSERVATION COMMISSION I SARAH PAUN, GOVERNOR 333 W. 7th AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Tim Brandenburg Alaska Drilling Manager Union Oil Company of California P.O. Box 196247 Anchorage,AK,99519 Re: McArthur River Field, Hemlock Oil Pool, D-20 Sundry Number: 307-032 SCANNED FEB 0 1 2007 \~~,oqS Dear Mr. Brandenburg: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may me with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, DATED this31 day of January, 2007 Enc!. elf 1/~/JìJl STATE OF ALASKA .. ALA_OIL AND GAS CONSERVATION COM~ON APPLICATION FOR SUNDRY APPROVALS 20 MC 25.280 l/trM \.,'v A'ftftl,^ na o. ("^~ "^fl~ si Abandon D Suspend [2] Operat:v' led :muroown 8- Perforate D .:-::-.,' rTI- '. U 1. Type of Request: Waiver A h Other Alter casing D Repair well 0 Plug Perforations 0 Stimulate 0 . .ne Drage Time Extension 0 Change approved program D Pull Tubing D Perforate New Pool D Re-enter Suspended Well 0 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Union Oil Company of California Development [2] , Exploratory 0 69-95 . 3. Address: Stratigraphic 0 Service D 6. API Number: P.O. Box 196247 Anchorage, Alaska 99519 50-733-20203~r-1'" r.: I \ Ie: n . 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: 0-20 Spacing Exception Required? Yes 0 No 0 . 9. Property Designation: ·z..3 ~ 10. KB Elevation (ft): 11. Field/Pool(s): ¡../~¡M.loJ-O" / &-( /. ~!·t Dolly Varden Platform ,A1::> (.... lð""~ 1 06' above MSL McArthur River Field "7 12. PRESENT WELL CONDITION SUMMARY , Total Depth MD (ft): .~ Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): ~ )7') 10, >D ¡, I.%~~ ;s¡ID/DZ-'l I'~~' ':>7 Casing Length Size MD TVD Burst Collapse Structural Conductor 358' 33 " 400' 399' Surface 2,964' 13 3/8" 3,006' 2,905' 3090 1540 I ntermed iate Production 9,632' 95/8" 9,674' 9,242' 5750 3090 Liner 1 ,017' 7 " 1 0,480' 10,003' 8160 7030 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 9,820' - 10,260' 9380' - 9795' 3-1/2" N-80 9644' Packers and SSSV Type: (2) BOT Mod "D", (1) BOT "FB-1" pkrs Packers and SSSV MD (ft): Pkrs @ 10,198' & 10,068' & 9601' Otis DK WLRBV ~ "\ 13. Attachments: Description Summary of Proposal [2] 14. Well Class after proposed work: <..!uspended / Detailed Operations Program 0 BOP Sketch 0 Exploratory D Development ~ I Service D 15. Estimated Date for Current , 16. Well Status after proposed work: .... ~"7/-\ l/)(,.. Commencing Operations: Oil D Gas D Plugged [2] Abandoned 0 17. Verbal Approval: Date: WAG D GINJ D WINJ D WDSPL 0 c Commission Representative: 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Steve Tyler 263-7649 Printed Name Tim Brandenburg Title Alaska Drilling Manager Signature '2..h ~/ Phone 263-7657 Date 1/23/2007 I __ A COMMISSION USE ONLY --- Conditions of approval: Notify Commission so that a representative may witness Sundry Number: )()'l-Q~ d-- Plug Integrity D BOP Test D Mechanical Integrity Test D Location Clearance D Other: RBDMS BFI., OJ 7007 "T ~ ;OMMISSIONER APPROVED BY Date: 18/-()r Approved by: THE COMMISSION I I Form 10-403 Revised 06/2006 L/~' ~ Submit in Du licate L:.. 11 FE. (,. o3S ORIGINAL h RECEIVED b-VAN 2 3 2007 on p ¿ø- ¡.'2.3.d/ í/'}T/tI; . . Dolly Varden D-20 WO Procedure Summary Discussion · Completion tbg and jewelry have been removed. · Hemlock production interval has been isolated with a pkr plug set in the FB-1 pkr @ 9601'. . 7" scab liner and tension hanger pkr have been removed. · 9-5/8" PC has been cleaned and drifted to 4270'. Tandem scrapper assembly had over pull running through breach area at 4276'. · USIT logging tool ran on 1/15/07 depicted an additional 9-5/8" csg breach at 4276',ín addition to the known breach at 1484'. No other integrity anomalies were depicted. PC appears to be in good condition. ~ · Champ pkr diagnostic work indicates a non-restricted circulation path exists behind the 9-5/8" PC from 4276' to 1484'. . Dressed 4276' area with 8.6" string mill. · RI set composite BP below Iwr csg breach @ 4276'. RI set composite retainer on DP above Iwr breach @ 4200'. · No Joy on establishment of circulation from 4276' to 1484'. Worked pumps at various rates & pressure. Managed to obtain circulation, momentarily, 21bbls with 12 bbls returned. · Squeeze 250 sx of cmt out csg breach @ 4276' (could not reestablish circulation). POOH. · Set FasDrill BP below upper csg breach @ 1531'. Lay-in 64 bbls of Cmt. Down Squeeze cmt to 2500 psi. only able to place 2 bbls out csg breach @ 1484'. · RIH wi Clean-out assy. Drilled/Clean-out cmt from 1100' to 1134'. Jug test wellbore to 1500 psi for 30 min. · NO BOPE. NO Csg spool & Spacer spool. NU BOPE's. Forward Plan · Continue NU BOPE. Test Same. · Drill-out cmt and BP. RI to top of cmt retainer @ 4200'. CBU. Displace wellbore to a pkr fluid. POOH. · RIH wi RTTS to below upper csg breach. Pressure Test csg, below breach, to 1500 psi to retainer @ 4200'. POOH. · RI wI 2800' of 3-1/2" kill string wI MS. Land same. NO BOPE. NU Tree. Test same. Release rig. · Turn Suspended 0-20 well over to production for monitoring. .........- RKB to TBG Head = 41.8' Tree connection: 4·116" 5,000# No Joyol12-111 thru pkr. during wo In 11/83 PBTD" 10,430' TD = 10,506' MAX HOLE ANGLE = 21°, @ 2100' Wt Grade 61 K-55 5 40 N-80 Butt 8.835 80 bbls cmt returns 43.5 8.755 1000 sx CBL Good Bond 2000' 5200' 43.5 N-80 8.755 CBL 9-5/8" Prod Csg Butt 1700 sx Good Bond S-95 8.681 8450' 9450' AR-95 Seal Lock 7" Liner N-80 X-Line 6.185 9463' 10,480" 8-112" 375 sxs In<.::ludes (2) sqz m:TAIL NO, DeDth m Item 0 CIW 4-1/2" EVE 8rd X Butt Tb£. Hanœr. 4200' NA Fasdrill Retainer. 4320' NA Fasdrill Bridge Plug I 9,601 4.0 Baker "FB-I" Pkr. wi 10' Seal bore ext. & bell "uide. wi "SB" Pkr PItI" 2 10,068' 3.25 Baker Model "D" Pkr. 10,078' 2.75 Otis "X" Nioole, size 2.75 10,086' 3.00 Bell Guide 3 10,198' 3.25 Baker Model "D" Pkr. 10,206' 2.625 Otis "Q" Niople, size 2.625 10,212' Mule Shoe 3050' 9,748' 10,506 o o o A 4/29/75 0-27 collided w/ 0-20 while drilling 17-1/2" surface hole. Communication to Inlet. Spotted 500sx ofG cmt @400' in 0-27. Possible length of breach in 13-3/8" is 1488' to 1497'. Penetration in 0-209-5/8" @ 1497'. 7/75 WO sqz'd 9-5/8" csg @ 1497' 4x. Total cmt placed 650 sx. Last Perf Date 10/30/1969 6/15/1992 6/15/1992 6/15/1992 Jul-75 Jul-75 Accum Amt. SPF 4 20 16 16 16 4 D-20 Proposed Wellbore Secure 12-06.doc SLT: 111l5/2006 RE: D-20 Restore Wellbore Integrity Sundry #306-394 --Suspension ... . . Tom No Joy in Mudville is correct. Our cmt job did not go as expected. We are not convinced that we were able to achieve our initial objective of securing the Wellbore with confidence. We like to maintain the ability to monitor, gather data and the ability to future remediate if necessary. We have sent a 403 Sundry to suspend the well for your approval. Let me know if you need anything more. From: Thomas Maunder [mailto:tom_maunder@admin.state.ak.us] Sent: Monday, January 22,20074:19 PM To: Tyler, Steve L Cc: Harness, Evan; Brandenburg, Tim C Subject: Re: D-20 Restore Well bore Integrity Sundry #306-394 --Suspension of Operations Steve, et aI, No joy in Mudville for this time at bat, however it appears that you are preserving your options. What sort of options does your crystal ball hold? Leaving the wellbore as you propose will need another sundry. By our regulations the well looks to be suspended. Look forward to your reply. Tom Maunder, PE AOGCC Tyler, Steve L wrote, On 1/22/20074:10 PM: Tom Below is a brief dissertation on where we are at on our 0-20 today. Discussion . Completion tbg and jewelry have been removed. · Hemlock production interval has been isolated with a pkr plug set in the FB-1 pkr @ 9601'. . 7" scab liner and tension hanger pkr have been removed. · 9-5/8" PC has been cleaned and drifted to 4270'. Tandem scrapper assembly had over pull running through breach area at 4276'. · USIT logging tool ran on 1/15/07 depicted an additional 9-5/8" csg breach at 4276', in addition to the known breach at 1484'. No other integrity anomalies were depicted. PC appears to be in good condition. · Champ pkr diagnostic work indicates a non-restricted circulation path exists behind the 9-5/8" PC from 4276' to 1484'. · Dressed 4276' area with 8.6" string mill. 10f2 1/26/2007 10:49 AM RE: D-20 Restore Wellbore Integrity Sundry #306-394 --Suspension ... . . · RI set composite BP below Iwr csg breach @ 4276'. RI set composite retainer on DP above Iwr breach @ 4200'. · No Joy on establishment of circulation from 4276' to 1484'. Worked pumps at various rates & pressure. Managed to obtain circulation, momentarily, 21 bbls with 12 bbls returned. · Squeeze 250 sx of cmt out csg breach @ 4276' (could not reestablish circulation). POOH. · Set FasDrill BP below upper csg breach @ 1531'. Lay-in 64 bbls of Cmt. Down Squeeze cmt to 2500 psi. only able to place 2 bbls out csg breach @ 1484'. · RlH wi Clean-out assy. Currently drilling out cmt on top squeeze job. Forward Plan · Continue Drill-out cmt and BP. RI to top of cmt retainer @ 4200'. CBU. Displace wellbore to a pkr fluid. POOH. · RlH wi RTTS to below upper csg breach. Pressure Test csg, below breach, to 1500 psi to retainer @ 4200'. POOH. · RI wI 2800' of 3-1/2" kill string. Land same. NO BOPE. NU Tree. Test same. Release rig. · Turn Suspended 0-20 well over to production for monitoring. Union Oil Company of California (Office: (907) 263-7649 (Cell: (907) 350-6295 (Home: (907) 696-1837 (Fax: (907) 263-7389 .Email: tïlersl@chevron.com 20f2 1/26/2007 10:49 AM . . SARAH PALIN, GOVERNOR A"tA~BA OILAlWD GAS CONSERVATION COMMISSION 333 W 7th AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Tim Brandenburg Alaska Drilling Manager UNOCAL PO Box 196247 Anchorage, AK 99519 5CANNED JAN 1 9 2007 Re: McArthur River Field, Hemlock/ G Oil Pools, TBU D-20 Sundry Number: 307-017 \~~Ð~5 Dear Mr. Brandenburg: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, DATED thisL/day of January, 2007 Encl. ,,/~ \ ú"" .r~ ~ J 0'1 Kt:\.."t:.1 V t:U ur 1/- STATE OF ALASKA A .4\1 I '>007 ALASØ'OIL AND GAS CONSERVATION COMM~N \ ""\ vAN 1 0 L APPLlCA rlON FOR SUNDRY APPROVALS .Aiaska Oil & Gas Cons. Crnnmíssion 20 MC 25.280 1. Type of Request: Abandon 0 Suspend 0 Operational shutdown 0 Perforate 0 Waiver 0 Other 0 Alter casing 0 Repair well 0 Plug Perforations 0 Stimulate 0 Time Extension 0 . Convert to ESP Change approved program 0 Pull Tubing 0 Perforate New Pool 0 Re-enter Suspended Well 0 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: - Union Oil Company of California Development 0 Exploratory 0 ~ \c,...<;. -öC; ~ 3. Address: Stratigraphic 0 Service 0 6. API Number: P.O. Box 196247 Anchorage, Alaska 99519 50-733-20203-00 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: 0-20 ~Tß\..),> Spacing Exception Required? Yes 0 No 0 9. Property Designation: 10. KB Elevation (ft): 11. Field/Pool(s): Dolly Varden Platform ,,ÁÞc,. It!> ?2.t:t .;:5ì> I- R:Þ.-7 106' above MSL . McArthur River Field 12. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 10,506' - 10,028' 10,040' 9,588' 10,040' Casing Length Size MD TVD Burst Collapse Structural Conductor 358' 33 " 400' 399' Surface 2,964' 13 3/8" 3,006' 2,905' 3090 1540 Production 9,632' 95/8" 9,674' 9,242' 5750 3090 Liner 1 ,017' 7 " 1 0,480' 10,003' 8160 7030 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 9,820' - 10,260' 9380' - 9795' NIA NIA NIA Packers and SSSV Type: (2) BOT Mod "D", (1) BOT "FB-1" pkrs Packers and SSSV MD (ft): Pkrs @ 10,198' & 10,068' & 9601' Otis DK WLRBV SSSV @ 328' 13. Attachments: Description Summary of Proposal 0 14. Well Class after proposed work: Detailed Operations Program 0 BOP Sketch 0 Exploratory 0 Development 0 Service 0 15. Estimated Date for 16. Well Status after proposed work: Commencing Operations: January 14, 2007 Oil 0 Gas 0 Plugged 0 Abandoned 0 17. Verbal Approval: Date: WAG 0 GINJ 0 WINJ 0 WDSPL 0 Commission Representative: 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Chantal Walsh 263-7627 Printed Name Tim Brandenburg Title Alaska Drilling Manager Signature .~~ ~/ Phone 263-7657 Date 1/5/2007 ¿,-- /7 COMMISSION USE ONLY y Conditions of approval: Notify Commission so that a representative may witness Sundry Number: ~1Jr¡ - () 1 '1 Plug Integrity 0 BOP Test ~ Mechanical Integrity Test 0 Location Clearance 0 Other: ?::l:$$:J'i(e.;, ~ a? ~~ ~ ~ '¡ 0\-\""\ \~ -V-, ~ ~~t-~~ '" ~o~\c~ -\c~-\- +c bc-~c~u ~~ wh""d-. W~ct\-c; Subsequent Form Required: ,-\()L\ fì ~ COMMISSIONER RBOMS 8Ft JAN 1 8 2007 APPROVED BY Approved by: THE COMMISSION Date: /-/:¡-tJ7- Form 10-403 Revised 06/2006 O'F< / jm Al - ~.. (- 1(,.'°7 ~t i/?UPlicat ( t7/t)7 . . Dolly Varden D-20 ESP Conversion Dolly Varden Platform Objective: Following well well repair operations previously submitted and approved in December 2006, the Well will be converted to an ESP completion. Procedure Summary: Well Workover (previously submitted) 1. PU Eventure expandable csg patch. RI w/ expand csg to isolate breach. POOH. LD tools. "30(9-~~~ f ~~-ç7 o.-'\. ~'{<:z~ 2. PU Drill/CO assy. RI drill/CO launcher at end of expandable liner. Pressure test wellbore. POOH. LD BHA. 3. Continue rig ops and move into ESP conversion procedure (suspension of operations not anticipated). ESP Conversion Procedure 4. RIH w/ retrieving tool. CO sand. Latch pkr plug (or Ret BP). POOH. LD same. 5. RIH w/pkr mill assy. Mill FB pkr @9601'. POOH w/same. (Utilize size salt to control losses). 6. RIH w/CO/junk basket assy. CO fill and various wireline fish from 10,040 to Mod D pkr @ 10,068'. POOH. 7. RIH w/pkr mill assy. Mill Mod D pkr @ 10,068'. POOH w/same. (may push to btm). 8. PUMU TCP perf guns. RIH and perf to add G - 1, 2, 3,& 4 zones. Reperforate, currently open, Hemlock benches. POOH~ (Utilize size salt to control losses). 9. PUMU ESP pump assy. RIH on 3-1/2" tbg w/ cable to +/- 9250'. 10. Land tbg. ND tree. Test same. Release Rig. Turn well over to production. RKB to TBG Head'" 41.8' C n Tree connection: 4·1fS" 5,000# Size 33" Conductor Surf 400' Driven 13-3/8" Surf Csg 61 K-55 Seal Lock 2.51 Surf 006' 17-1/2" 2350 sx urf 150 sx Too sx Total A1 9-5/8" 40 .835 Surf cmt returns Prod Csg 43.s N-80 Butt .755 4390' 1 000 sx ood Bond , 5200' ~ ~ 8.755 5206' 6156' 12-1/4" N-80 CBL 9-5/8" Prod Csg Butt 6156' 7080' 1700 sx Good Bond ~ 47 S-95 8.681 7080' 9072' 8450' 9450' f5 AR-95 Seal Lock 9072' 9674' "' 9960' TOC 375 sxs 9663'-9669' & 7" Liner 29 N-80 X·Line 6.185 9463' 10,480" 8- !/2" 9677'~9680' & Includes (2) sqz 9744'-9749' CBL 9-5/8" xpandable Csg Patch Collapse=2820 psi) 7.90 1450' 1550' 1 Tubing 41.8' RKB to Thg Hngr 3-1/2" I 9.2 N-80 I Butt 2,992 Surf I '*'9250' ~;SP Cabl" wi (2) 318" 9(WB HiS GAL "..,,, 2 G Y DETAIL one Perfs NO. De!)}/¡ m ~m ~ Sì 0 4-1/2" X 3-1/2" Butt Thg. Hanger. 1 ±9240' 2.813 3-1/2" Sliding Sleeve 2 ±9250' ESP 3 10,189' 3,25 Baker Model D Packer 4 10,206' 2.625 Otis "Q" Nipple, size 2.625 s!8hoe 5 10,212' Mule shoe ('it ;!î @9660' OIL /;m ~¡ ¡;,¡ ¡Wi¡ B-1 . & Info: Spudded 0-20 on 9/20/69. TO @ 10,506' on 10/25/69. Completed & RR on 11/06/69. -Hole Secnon MWT: -Approximate Rotanng Itrs: 13-3 0 17-1/2" to 3050' 9.9 to 10 ppg 0 33" 60 hrs 0 12-1/4" to 9,748' 9.8 to 10 ppg 0 13-3/8" 285 hrs 0 8-1/2" to 10,506 0 9-5/8" 48 hrs 0 T' 16 hrs 13-4 A 4/29/75 0-27 collíded wi 0-20 while drilling 17-1/2" surface hole. Communication to Inlet Spotted 500sx ofG cm! @ 400' in 0-27. Possible length of breach in 13-3/8" is 1488' to 1497'. Penetration in 0-209-5/8" @ 1497'. 7/75 WO sqz'd 9-5/8" csg @ 1497' 4x, Total cmt placed 650 sx. DATA i Accum Last 8·5 I SPF Perf Date Zone Top 8tm Amt. Present Condition G 9338' 9348' 10' Proposed Perfs No Joy on 2..1/ G 9370' 9388' 18' Proposed Perfs thru pkr. during woIn 11J83 G 9420' 9430' 10' Proposed Perfs G 9418' 9488' 10' Proposed Perfs ~680' 9,681' 1 ' 4 11/2/1969 Sqz 100 sx cmt. Sqz 9,750' 9,751' 1 ' 4 10/30/1969 Sqz 75 sx cmt. B-6 B-1 9,820' 9,885' 65' 20 6/15/1992 I Production æ"950' 45' 16 6/15/1992 I Production B-4 10,065' 115' 16 6/15/1992 Open fl Production "'- 10,190' 120' 1 Jul-75 Open fl Production P8TD" 10,430' TD = 10,506' MAX HOLE ANGLE = 21°, @ 2100' 8-6 30' 4 Jul-75 Open fl Production D-20 Proposed ESP Schm 11-06.doc CRW: 01/2007 A 4, 1/16" 5M Foster HCR Valve B 4 1/16" 5M Manual gate valve C 3 1116" 5M Manual gate Kill line I) 3 1/16" 5M Manual gate Kill line Top of drill deck . . Review of Sundry Applications 307-017 Union Oil Company of California Well Trading Bay Unit D-20 McArthur River Field, Multiple Pools AOGCC Permits 169-095 Requested Action: Union Oil Company of California (Unocal) proposes to convert an existing development wellbore to ESP service, reperforate existing intervals and perforate new intervals. Recommendation: I recommend approval of Unocal' s proposed actions Discussion: Unocal proposes to convert the subject well to an ESP completion following previously approved wellbore repairs. Additionally, they propose to reperforate the existing intervals within the Hemlock Oil Pool and to add new perforations in the Middle Kenai "G" oil pool. Commission regulation 20 AAC 25.21 5 (b) requires Commission approval prior to commingling production from multiple pools within a single wellbore. Conservation Order 234A dated December 21, 1993, pennits downhole commingling of production from the Middle Kenai "G", Hemlock, and West Foreland oil pools throughout the McArthur River Field. Therefore, Unocal's proposed activities are being conducted in accordance with an approved conservation order and no additional Commission action is required to authorize this instance of downhole commingling. Conclusion: Since the proposed actions comply with Commission regulations and an existing Conservation Order it is appropriate to authorize Unocal to perfonn their requested actions. ~ D.S. Roby ~ Reservoir Engineer January 17, 2007 . . SARAH PALIN, GOVERNOR AI~~1iA OIL AND GAS CONSERVATION COMMISSION 333 W 7th AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Tim Brandenburg Alaska Drilling Manager Union Oil Company of California PO Box 196247 Anchorage, AK 99519 ,,", iI. ~'k'æ;:¡¡'\' ðt;~M ~~~~,G)} çp r· (..5 Re: McArthur River Field, Hemlock Oil Pool, D-20 (TBU) Sundry Number: 306-394 \\9\,\OqG Dear Mr. Brandenburg: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, DATED this ~ay of December, 2006 Encl. . . Chevron === Timothy C Brandenburg Union Oil Company of California Drilling Manager P.O. Box 196427 Anchorage, AK 99519-6247 Tel 907 263 7657 Fax 907 263 7884 Email brandenburgt@chevron.com December 13, 2006 EC;EIVED DEC 1 4 2006 Tom Maunder Alaska Oil & Gas Conservation Commission 333 W. ¡th Avenue Anchorage, Alaska 99501 & Gas Cons. Commission Anchorage Re: Dolly Varden 0-20, Application for Sundry Approval Dear Mr. Maunder, Attached for your approval is an Application for Sundry Approval (Form 10-403) for the above referenced well. The proposed work will be undertaken to restore the integrity of Well 0-20. _ '\ ,_ r\'"\S-C)';)~ ~ ~ ~ ~'\--.\,.:)~ \q'"1~ In 1975, while drilling Well 0-27, Well 0-20 was struck and the 9-5/8" casing breached at 1497'. This breach was repaired by squeezing cement and running a 7" liner back to surface. The well was produced until pressure communication between the tubing x 7" liner and 7" x 9-5/8" annulus was noted, and the well was shut-in. The well has remained shut-in since that time. ~ '-10..)1(:.\\ ~-:s: ~,~s;'" As part of our ongoing well bore integrity management program, we have identified 0-20 as a candidate for intervention. The failed scab liner along with the known breach in the existing production and surface casing string warrants further intervention. If this proposed intervention is successful, 0-20 would be a candidate for a conversion to an ESP completion or a redrill.'/ If you have any questions, please call me at 263-7657 or Mr. Steve Tyler at 263-7649. Sincerely, ~__C~~é?~/5 ,.f"'· TimothYC. Brandenburg Drilling Manager ,....-....- ...-.~ ,/ I ~' /'" Attachment TB:sk Cc: Well File Steve Tyler Union Oil Company of California / A Chevron Company http://www.chevron.com . . Dolly Varden D-20 Cover Sheet Brief Discussion: D-27 collided with D-20 in 1975 @ 1480'(MD from D-27). During the subsequent workover on D-20 a breach in the 9-5/8" csg was found @ 1497'. . -. \~ ~/~ , b~o-L~~ 0-.,,> u-.,)~\' M-?}1/( P/l'\ The breach in D-20 was squeeze with 650 sx of cmt and tested to 1500 psi. A scab liner was then run from surface to 1723' and tested to 1500 psi. A WO in 1983 changed out the gaslift string. Currently the well is shut in due to pressure communication from 7" x tbg annulus with all other annuli. This proposed workover is to restore well bore integrity. RECE'Vt::U _ STATEOFALASKA~/~ I . ALA" OIL AND GAS CONSERVATION COM-.sìoN tr'''b_' DEC 1 4 2006 APPLICATION FOR SUNDRY APPROVALS AI k O\I&G C C ., 20 AAC 25.280 as a I as ons. omrmsslOn 1. Type of Request: Abandon 0 Suspend 0 Operational shutdown 0 Perforate 0 Waiver f!!]cnorage Other 0 Alter casing 0 Repair well 0 Plug Perforations 0 Stimulate 0 Time Extension 0 Change approved program 0 Pull Tubing 0 Perforate New Pool 0 Re-enter Suspended Well 0 2, Operator Name: 4. Current Well Class: 5, Permit to Drill N.umber: Union Oil Company of California Development 0 Exploratory 0 69-95 3. Address: Stratigraphic 0 Service 0 6. API Number: P.O. Box 196247 Anchorage, Alaska 99519 50-733-20203-00 7, If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: 0-20 <.. T"ß '-.J) Spacing Exception Required? Yes 0 No 0 9. Property Designation: ,tÞ 10. KB Elevation (ft): 11. Field/Pool(s): ¿ A> Dolly Varden Platform ,4-Þ( 181 z.c.r ì¿ If,~ 106' above MSL McArthur River Field ¡4>KkvL (!)/ 1 . =1 Ii I?ðtc 12, PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 10,506' 10,028' 10,040' 9,588' 10,040' Casing Length Size MD TVD Burst Collapse Structural Conductor 358' 33 " 400' 399' Surface 2,964' 13 3/8" 3,006' 2,905' 3090 1540 Scab Liner 1,681' 7 " 1,723' 1,704' 8160 7030 Production 9,632' 95/8" 9,674' 9,242' 5750 3090 Liner 1 ,017' 7 " 1 0 ,480' 10,003' 8160 7030 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 9,820' - 10,260' 9380' - 9795' 3-1/2" N-80 9644' Packers and SSSV Type: (2) BOT Mod "D", (1) BOT "FB-1" pkrs Packers and SSSV MD (ft): Pkrs @ 10,198' & 10,068' & 9601' Otis DK WLRBV SSSV @ 328' 13, Attachments: Description Summary of Proposal 0 14. Well Class after proposed work: Detailed Operations Program 0 BOP Sketch 0 Exploratory 0 Development 0' Service 0 15. Estimated Date for 16. Well Status after proposed work: Commencing Operations: December 18, 2006 Oil~ Gas 0 Plugged 0 Abandoned 0 17. Verbal Approval: Date: WAG 0 GINJ 0 .. ~J 0 WDSPL 0 Commission Representative: . v:">\), ~ Q U~r/( I.)/; ~ :::. ~ -. . 2) I 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Steve Tyler 263-7649 Printed Name Tim Brandenburg Title Alaska Drilling Manager - Signature .-//~~ /S ...~e 263-7657 Date 12/12/2006 ..--"><:-~·é -.- /' ./ //-;;f COMMISSION USE ONLY , -' Conditions of approval: Notify Commission so that a representative may witness Sundry Number: ?n'n -,:2ÇJ-4 Plug Integrity 0 BOP Test ø--- Mechanical Integrity Test 0 Location Clearance 0 Other: 3VOD~7\ ß-af' ~'> \- Subsequent Form Required: ~M ~A APPROVED BY Date: 11--; ~ ,-()þ Approved by: / - VoiOMMlt SIONER THE COMMISSION emt 5+N A L ClSDMS"at'L DEC 26 1006 ~. ..~ I"L· l¡r.~ Form 10-403 Revised 06/2006 Submit· Duplicate /;2 - ~ (~¡b¿- . . it Dolly Varden D-20 WO Procedure Summary ~O~CQ~\:)""\-cS~-r~\~ wo~ '. l ~.~\~ ~ ~e:0 ~ MobeRigontoD-20.NDtree.NUBOPE.Testsame. ~ w\\ ~F~ ~/{J\.' þ~_ ð~~t'- h ~ .,' \)",)k.\\ ~ \oC0 " \)\{T ~\L\ ~\~\'1" PU Remove tbg hngr. POOH wi tbg. LD same. 5 -f\ A 'SL~ (:::ff K). , ;)-\ PUMU BOT pkr plug. RIH on DP. Set in FB-1 pkr @ 9601'. Spot 10sx of sand on plug. Fill wellbore wi FIW. POOH. c..'-Jç-~~\-- ,\,\'.J.::::"'S-")"~":::. \:Cl\~ .'-\ ~ S"' -(öòj.. Contingency: will utilize a 7" retrievable BP if we have to cut tbg. · · Jfwe are Cl Bust on cleaning out to the 7 we are thinking our best option lvould be 1) Form - a plug pill on top of tub íng fish·- Then cement plug on top (~lth(tt These options will isolate uSþ'om Zone - We 1rill still have the leak problem at the current Scab/breach (Test pressure (~lisolation }vÏll be compromised) · PUMU 7" spear. Spear 7" scab. ND BOPE. PU stack. PU 7" (note: 7" set w/ 80k tension) remove slips. NU BOPE. RI unset tension hngr. POOH. LD 1681' of 7" scab liner. Currently plan to change Rams to 7 ,. prior to picking up Stack - This part is sorne}fhat qfa sticlg.' wicket - Records' show that the install was lrith a cone type liner hanger on the btm (!lthe existing scab - +/- 80k l!iaS pulled and slips lvere set in H'ellhead 1) Canlre get enough 1110Vemen! to get 7 '.' slips out of\vellhead 2) Can lFe get upside-dmrn ¡iner hanger to release (S'lack (4/10 neutral and 1/2 turn to ''J'') 3) Þ-f;7l11 7 t. r(llnS loade(llFe lrollld l](J! hClve c()'verage or; tIle ¡.S)Jear as\)~elllbl..v but lre lvill11ave to Pick the stack to get slips oul 4) fllFe cannot get hanger to release then llrill be exposed to another ram change back to D. r. to chase the liner down hole atiernpting to get a release (isolationfi"om productive Zone lvill be as above 5) Reluctance to add a ram cavity is due to the height lFe will be able to pick {he stack to lvork on 7" slips in -.rellhead 6) Test Plug + Ram Change +- Shell test (~rBOP qf'ter Laying dmvn 7" · PUMU 9-5/8" csg scraper. Rl to 3000'. POOH. · RU Eline. PUMU USIT Logging tool. RlH log from TOL @ 9463' to 1200'. POOH. RD Eline. Evaluation (?fthis Casing inspection Log along with Pressure testing work ìvill drive the expandable location Clnd length . PUMU RTTS. RI Set RTTS @ 1550'. Test PC below RTTS. PU to 1450'. Set & test PC above RTTS. POOH. Test Pressure I' 500psi over ìForkover Fluid . PUMU HES Ret BP. RI & Set BP @ 2000'. PU spot 10 sx of sand on top ofBP. PU to 1400'. · Mix pump/circulate 500 sx of emt to EODP. SI returns. Cont pumping cmt into csg breach @ 1497'. Allow 20 bbls fluid returns on 9-5/8" x 13-3/8" annulus. Sqz remaining away. Z;een lForking ¡ , aole to get is ¡llL!! lve exte?lt O!7eJ? to SjJ(!ce to J)lug - {j'jj is {lbreecJl1rith SOIne nor give l/''y' U lot ~l'enCOl!r(lgelnent in being {¡hIe to (icfliev£! . . a good pressure test (Short version = Large amounts alcement at these depths lvill not make the fònnation stronger)- j\lechanical patch required · CBU. POOH. WOC 12 hrs. · PU CO assy. RIH. Drill/CO cmt to 1570' 0 Pressure test 9-5/8" csg fl 30 min. Test pressure=: 1500psi over lvorkover fluid - Current Plan is to be Rigged up jòr 2 squeeze - ¡\;fight talk to AOGCC' abour Test Pressure on Squeeze · Continue RIH. CO to RBP. POOH. PU HES Ret tool. RIH ret RBP. POOH. LD same. · PU Eventure 100' expandable csg patch. RI Expand csg fl 1550' to 1450'. POOH. LD tools. Attached belen!' is the Enventure "Solid Expandable Tubular" (SET) f¡~format¡on along with a suggested running procedure that Enventure provided ¡14r. Tyler l,vhen this project first started - Some srnall changes l,vere made to the running procedure ~ E: \Merr6tick\USB transfer\DoIIy\D-20W · PU Drill/CO assy. RI drill/CO Launcher @ end of expandable liner. Pressure test well bore. POOH. LD BHA Test Pressure 1, 500psi over lvorkoverfluid · PUMU 3-112" tbg kill string. RIH to 9300'. PUMU tbg hng. Land tbg. ND ~OPE. NU Tree. Test same. ~emobe rig. . ""-Jc \'- :;'\\J~ ';;> ~>~iè~j ~ \-\:~:> -\\f~ PossIbly a 2 to 3 months suspenSIOn of operatIOns. . , X. We are currently }mrking to get equipment and AFE in place to allow us to run the ESP on this ~~ A1Óbilization tlsucces4itllvžth above lvork - May be sorneIvhat ambitious to get Mone.y in tÚne b \ but IFe are working on it · · Mobe Rig onto D-20. ND tree. NU BOPE. Test same \~ . ~ b PU Remove tbg hngr. POOH wI tbg. ~ "'-\¿;~ ';. -...) \~ '\"1 .~ "-ö~ \.<J , ~<è.--. RIH wi retrieving tool. CO sand. Latch pkr plug (or Ret BP). POOH. LD same '>()\,)1"'\...\-\\ ~J. \ü~~~ ~Y<"'" MJ~,-( RIH wI pkr mill assy. Mill FB pkr @ 9601'. POOH wI same. (Utilize size salt to control losses)" - i RIH wi COljunk basket assy. CO fill and various wireline fish from 10,040' to Mod D pkr @ 10,068'. POOH. RIH wI pkr mill assy. Mill Mod 0 pkr @ 10,068'. POOH wI same. (may push to btm) PUMU TCP perf guns. RIH perf9338'-9348' & 9370'-9388' & 9420'-9430' & 9439'-9449' to add G-l, 2 & 3 zone(s). POOH. (Utilize size salt to control losses) PUMU ESP pump assy. RIH on 3-112" tbg wI Cable to ±9250'. Land tbg. NO BOPE. NU tree. Test same. Release Rig. Turn well over to production. · · · · · · · · . . // f /" f ,/ ./ ;/> 1-/'// /' /' · PU Remove tbg hngr. POOH w/ tbg. LD same. ,/ /' · PUMU BOT pkr plug. RIH on DP. Set in FB-l pkr @ 9601'. Spø{ 1 Osx of sand on plug. Fill wellbore w/ F1W. POOH. // Contingency: will utilize a 7" retrievable BP if we have fJ/cut tbg. · PUMU 7" spear. Spear 7" scab. ND BOPE. PU stac~.p~ 7" (note: 7" set w/ 80k tension) remove slips. NU BOPE. R1 unset tension hngr. PQØ~\Ð 1681' of 7" scab liner. · PUMU 9-5/8" csg scraper. R1 to 3~~OOH: ' · RU Eline. PUMU US1T Logging t~J&'I!íog from TOL @ 9463' to 1200'. POOH. RD Eline. · PUMU RTTS. RI Set RTTS @ .~ :}~T~st PC below RTTS. PU to 1450'. Set & test PC above RTTS. POOH. ,~ ./ · Eline perforate 10' above cs:6;each @ 1497'. · PUMU HES Ret BP. R1 & ~èt BP @ 2000'. PU spot 10 sx of sand on top of BP. PU to 1400'. / · Mix pump/circulate 400 sx of cmt to EODP. S1 returns. Cont pumping cmt into csg breach @ 1497'. Allow 20 bbls flúid returns on 9-5/8" x 13-3/8" annulus. Sqz remaining away. Dolly Varden D-20 WO Procedure Summary · Mobe Rig onto D-20. ND tree. NU BOPE. Test same · CBD. POOH. W0912 hrs. · PU CO assy. R~H. Drill/CO cmt to 1570'. Pressure test 9-5/8" csg f/ 30 min. · Continue R1.{t:CO to RBP. POOH. PU HES Ret tool. RIH ret RBP. POOH. LD same. f · PU Enve. e 100' expandable csg patch. R1 Expand csg f/ 1550' to 1450'. POOH. LD tools. · PU Dr' /CO assy. RI drill/CO Launcher @ end of expandable liner. Pressure test wellbore. POQ . LD BHA · P U 3-1/2" tbg kill string. RIH to 9300'. PUMU tbg hng. Land tbg. D BOPE. NU Tree. Test same. Demobe rig. Suspend Operations for possible ESP Conversion. A 4 1/16" 5M Foster HCR Valve B 4 1/16" 5M Manual gate valve C 3 1/16" 5M Manual Gate Kill line D 31/16" 5M Manual Gate Kill line 13 518" 5M){ 11" 5M Cross over Spool Top of Drill Deck RKB to TBG Head'" 41.S' M#1 ~ ~ M#2 E ~ GLM#'3 GLMII4 GLM #5 ~ ~ 4 !t~ B ~ ~ . IT~í B-1 :: 8-3 Fill tagged on 6/25104 @ 10,040' ~(o'T:¡ . :;~6%~9@d 1~~201' :B~5 No Joy on 2-1/1 thru pkr. during WO In 11/83 / '~, e Wt Grade tor I 13,3/8" Surf Csg K,55 9,518" Prod Csg N-80 43.5 ~ N,80 9-5/8" Prod Csg 47 S,95 AR-95 7" Liner 29 N-80 ~ NO. sg Shoe 9660' OIL 1 ~ GLM #4 GLM #5 GLM #6 GLM #7 GLM #8 G~M #9 t 4 5 6 7 8 9 10 Delltll ° 328' 2,467' 4,311' 5,637' 6,766' 7,563' 8,184' 8,621' 8,944' 9,147' 9,599' 9,601 9,644' 10,068' 10,078' 10,086' 10,198' 10,206' 10,212' m 8-4 Cas na & Tu Thnl m Too ~ Surf 400' Seal Lock 1251 Surf 3006' 17,1/2" 2350 sx ~5 150sxTop 2500sxTotal Butt 8 835 4390' 80 bbl, em! returns 8755 '5204' 1000 sx CBL Good Bond 2000' 5200' I 8755 12,114" 11 a Butt 5206' 6156' 6156' 7080' 7080' 9072' 9072' 9674' 9463' 10,480" 8-1/2" 375sxs Includes (Z) sqz 9960' TOC 9663' ~9(i69' Ik 9677'-9680' & 9744' ·9749' CBL 8.681 Seal Lock I 1700 sx CBL Good BOnd 8450' 9450' X,Line 6.185 Surf 1723' I lIutl I 2.992 Surf I 2.75 2.75 2,75 2.75 2,75 2.75 2.75 2.75 2,75 iiTWiT¡ .ÐV OPT.. n Ue.m CIW 4,1/2" EUE 8rd X Butt Tbg. Hanger. 3 1/2" Otis Series DK '>.n~RBV SCSSV US" ro Locked out TREV 3-1/2" Cameo KBUG Mandrel wi 1,0"BK valve w/BK-2 Latch 3,1/2" Cameo KBUG Mandrel wi 1,0" BK valve wi BK,2 Latch 3-1/2" Cameo KBUG Mandrel wi 1.0" BK valve wi BK-2 Latch 3,l/2" Cameo KBUG Mandrel wi 1,0" BK valve wi BK,2 Latch 3,l/2" Cameo KBUG Mandrel wi 1.0" BK valve wi BK,2 Latch 3-1/2" Cameo KBUG Mandrel wi 1.0" BK valve wi BK-2 Latch 3-1/2" Cameo KBUG Mandrel wi 1,0" BK valve wi BK-2 Latch 3,1/2" Cameo KBUG Mandrel wi 1,0" BK valve wi BK,2 Latch 3-1/2" Cameo KBUG Mandrel wi 1.0" BK valve wi BK-2 Latch Baker Locator Seal Assy, 14' long" 4" X 3" Baker "FB-I" Pkr, wi 10' Seal bore ex!. & ben guide Baker 112 cut Mule Shoe Baker Model "D" Pkr. Otis '"X" Nipple, size 2.75 Ben Guide del "D" Pkr. Otis "Q" Nipple, size 2.625 Mule Shoe 4.0 2.94 3.25 2.75 3.00 3.25 2.625 II 1723' 6.1115" TIW'" R",,,f n".",¡¡~ ~'Î¡: Info: Snudded 0-20 on 9/20/69. TD @11O,506' on 10/25/69, Completed & RR on 11/06/69, oHole Section MWT: oAnnroximate Rotatin!!' Ius: o 17,1/2" to 3050' 9.9 to 10 ppg 0 33" 60 hrs o 12,1/4" to 9,748' 9.8 to 10 ppg 0 ]3,3/8" 285 hrs o 8-1/2" to 10,506 0 9-5/8" 48 hrs o 7" 16 hrs 5 iA 4/29/75 0-27 coJlìded w/ 0,20 while drilling 17-1/2" surface hole, Communication to Inlet. Spotted500sx ofG cmt @400' in 0-27. Possible length of breach in 13,3/8" is 1488' to 1497'. Penetration in 0-20 9-5/8"@ 1497'. 7/75 WO sqz'd 9-5/8" csg @ 1497' 4x. Total cmt placed 650 SX, Ran T' scab liner w/ TIW tension pkr,Pulled 80ktension. 8-6 ~ Accum Zone To Btm Amt. SP!' '1' 4 , 1': 4 B-1 9,820' 9,885' ¿ 20 B-3 9,905' 9,950' 45' 16 "- PBTD" 10,430' TD" 10,506' MAX HOLE ANGLE" 21°, KOP @2100' B,4 B,5 ß,6 D-20Schm 12-83 .doc 16 16 4 Last Perf Date 11/2/1969 10/30/1969 6/15/1992 6/15/199 6/15/1992 Jul,75 Jul,75 FISH: (5) "Donut Cups" off strip gun, 8/30/88 40' ± 0[,125 Wire 6/28/90 Lost 1-3/4 of X-Lock keys f/ SCSSV 1/26/94 @ 10,052' WLM @ 10,067' WLM @ 10,078' WLM Present Condition SQZ 100 $X cmt. SQZ 75 sx cmt. ODen f/ Production oduction en fl Production Open f/ Production Open fl Production REVISED BY: SLT: 10/23/2006 Æ 1000 sx 7" 43.5 N,80 Prod Csg Butt 47 S-95 8,681 AR,95 Seal Lock Liner 29 N,80 X-Line 6.185 9463' 6185 1450' 10,480" 8,1/2" 375 sxs Includes (2) sqz 80 bbls cmt returns CBL Good Bond 2000' 5200' CBL Good Bond 8450' 9450' 9960' TOC 9663'~9669' & Q677>968()' & 9744'~9749' CBL m 2 ~ 1700 sx 1 2 o 9,601 10,068' 10,078' 10,086' 10,198' 10,206' 10,212' CIW 4,112" EUE 8rd X Butt Tb ,Han er. Baker "FB,l" Pkr. wi 10' Seal bore ext & bell uide, wi "SB" Pkr Plug Baker Model "D" Pkr, Otis "X" Ni Ie, size 2.75 Bell Guide Baker Model "D" Pkr. Otis "Q" Ni Ie, size 2.625 Mule Shoe 4/29/75 0-27 collided w/ 0-20 while drilling 17,1/2" surface hole. Communication to Inlet. Spotted 500sx ofG cmt @ 400' in 0,27. Possible length of breach in 13-3/8" is 1488'to 1497'. Penetration in 0-209-5/8" @ 1497'. 7/75 WO sqz'd 9-5/8" esg @ 1497' 4x. Total emt placed 650 sx. 3 4,0 3.25 2.75 3.00 3.25 2.625 S udded D,20 on 9/20169. TD .Hole Section MWT: o 17,112" to o 12-114" to o 8-1/2"!0 3050' 9,748' 10,506 o o o No Joy on 2.-1 :o"'::~~'J:~rlng Amt 10' Sqz 8-1 6 B-3 8-4 8-5 B-6 PBTD '" 1 0,430' TD '" 1 0,506' MAX HOLE ANGLE'" 210, @ 2100' D-20 Proposed Wellbore Secure 12-06.doc SL T: 11/15/2006 . . ENVENTURE SfT. The Stòndard.w Solid Expandable Tubular (SETTM) Installation Procedure 7-518 X 9-518 40 Iblft Cased-hole Liner (CHL TM) Chevron Alaska Well # D-20 Trading Bay Unit Cook Inlet, Alaska 29 November 2006 Prepared by: Neal Keith Office: 281.552.2200 Cell: 281.627.4067 Fax: 281.552.2201 E-Mail: Neal.Keith@enventureGT.com Version 2.0 This document contains information that is confidential and proprietary to ENVENTURE GLOBAL TECHNOLOGY and should not be isclosed to third parties without prior written permission from ENVENTURE GLOBAL TECHNOLOGY. Chevron Alaska OBJECTIVE: . . Cook Inlet #0-20 Safely and successfully install an expandable 7-518 X 9-5/8 in. 40 Ib/ft Solid Expandable Tubular (SETTM) Cased-hole Liner (CHL TM) system. The purpose of the installation is to repair a hole in the existing 9-5/8 in. casing (-1 ,488 ft MD) caused by offset well drilling into borehole. WELL DATA: Well Name: Field Name: Rig: Rig Phone: Base Casing: Mud Type: Mud Weight: Setting Depth: BHT: Inclination: 0-20 Cook Inlet 9-5/8 inAO Ib/ft ISW (Inlet Sea Water) 8.5 ppg Expandable liner to be set from -1,438 ft to -1,547 ft Est. 1700 F static 50 deg @ set depth Vertical Well SOLID EXPANDABLE TUBULAR DATA: PRE-EXPANSION SPECIFICATIONS POST-EXPANSION SPECIFICATIONS Grade EX-80 Optimum Torque 2,500 ft-Ibs Nominal Yield 80,000 psi Collapse 2,940 psi Nominal Weíç¡ht 29.70 Ib/ft Nominal Weight 31.24 Ib/ft Nominal OD 7.625 in. Nominal 00 8.609 in. NominallD 6.875 in. NominallD 7.900 in. Drift I D 6.750 in. Drift 10 7.821 in. Wall 0.375 in. Wall 0.354 in. Internal Yield 6,890 psi Internal Yield 5,760 psi PRE-JOB ACTIVITIES: 1. The base casing and any other equipment, such as BOP stack and the wear bushing, that the liner hanger will be run through or expanded through, must be inspected for adequate clearance and all dimensions must be verified. 2. The expandable liner will be received on location and will be unloaded (Prepare pipe racks casing pin pointing to rig) using the specified Enventure handling procedures to prevent damage. The liner will be drifted, the threads will be cleaned, visually inspected, and seal rings will be installed. All thread cleaning must be done safely with no environmental consequence. This document contains information that is confidential and proprietary to EN VENTURE GLOBAL TECHNOLOGY and should not be disclosed to third parties without prior written permission from EN VENTURE GLOBAL TECHNOLOGY. Page 2 of 6 -Chevron Alaska . . Cook Inlet #D-20 3. Sufficient drillpipe must be available to replace any drill collars that might have been used in cleaning out the well. All workstring components will be drifted (the drillpipe will be drifted with standard drift size - 1.90 in. 00 drift is the minimum drifting 00). 4. The hole should be well circulated; the fluid should be properly conditioned for running the liner. Clean fluid is needed to fill the liner while it is being run. Clean fluid (Secondary lubricant will be required) should also be used for the expansion of the liner. 5. The cleanout trip should consist of two stacked 8.599 in. full gauge stabilizers with an 00 the same as the launcher (8.599 in.) and a casing scraper. This is to ensure that the base casing diameter is large enough, that there is sufficient clearance available for the expansion, and there are clean areas for elastomer cladding. 6. Circulate hole clean, drop hollow drillpipe drift/rabbit, if well conditions allow, and pull out of hole to run liner. All drillpipe and BHA components should be clean, drifted and free of internal scale. Orillpipe not drifted in the hole is to be drifted in the derrick. 8. A 15° to 30° internal shoulder taper will be maintained on all liner-running BHA components when possible. This includes backup assemblies of all critical components. . NOTE: If drilling jars are used in the expansion workstring, they should be pressure-tested to 6,000 psi prior to transporting to job site. NOTE: Maximum allowable pressures must be confirmed before testing lines prior to expansion. INSTALLATION PROCEDURE: 1. Conduct safety meeting prior to rigging up and at any tour change or change of personnel. Record all attendees on sign-in sheet. 2. The liner running equipment should be inspected and tested on-site prior to the actual installation. Confirm that all slips, elevators and safety clamps are equipped with low penetration dies and slip segments. When possible, the tong torque dump settings and gripping capacity should be tested with a pup joint prior to rigging them up on the rig floor. Rig up liner running equipment. The liner will be run using single joint elevators, side-door elevators and hand slips. Rig up torque monitoring equipment. The torque monitoring equipment will confirm a properly torqued connection. 3. All SET will be run with Enventure lift nubbins. · NOTE: These nubbins are made from P-110 material and are stronger than the EX-80 connection. The nubbin will support the entire weight of the SET string. The EX-80 pipe has a special left-hand thread, flush joint XPC connection and will, be run pin-up. 4. Pick up the lower Anchor Hanger/Launcher and install in rotary table. Carefully guide launcher through the rotary while being lowered in the hole. Ensure proper precaution is taken to prevent damage to the external elastomer coating on the hanger when running it into the well. Take every precaution to ensure that the hole is covered whenever possible. · NOTE: Lower Anchor Hanger/Launcher will be assembled in the shop prior to delivery to the location. Total length of this assembly will be - 25.00 ft. The assembly will include the launcher with the expansion cone, the mandrel and the safety sub installed. Float shoe will be installed on bottom of launcher and will be bull plugged. The top connection will be an XPC LH pin. The launcher and lower Anchor Hanger will be torqued in Enventure's shop. This document contains information that is confidential and proprietary to EN VENTURE GLOBAL TECHNOLOGY and should not be disclosed to third parties without prior written permission from ENVENTURE GLOBAL TECHNOLOGY. Page 3 of 6 ,Chevron Alaska . . Cook Inlet #D-20 · NOTE; At this time, Enventure Project Manager will pour secondary lubricant into the launcher assembly positioned on the slips. Amount will depend on final determined length of liner. · NOTE: An Enventure Project Manager will inspect and clean each connection, then apply thread compound while joints are being picked up (in slips). The thread compound FlexLube X will be supplied by Enventure. 5. Install a pipe wiper for the liner on the first joint of expandable liner after running the lower hanger assembly. . NOTE: Hole covers should be used to cover both the top of the liner and the wellbore any time hand tools or other similar items are being used around them. 6. Make up and run _joints of Enventure 7-5/8 in. liner. A safety clamp with low-penetration dies should be used as long as the loads are within the manufacturer's recommended load capacity. The safe working limits of the safety clamp should be verified with the provider of the clamp. · NOTE: This SET liner is run pin-up and has a left-hand thread. Connection sleeves (0.060 ATC in. wall thickness) will be run on all joints. The torque requirement for this connection is 2,500 ft-Ib. · NOTE: The yield torque of the XPC connection is 5,600 ft-Ib. 7, Fill the liner with fluid at each joint (flush the fillup line before filling up the liner the first time. Also, at this time it is recommended to pick the liner up and check for damage caused by the slips and to also make sure the rig is centered over the hole. 8. Stop filling the liner after _ joints to avoid displacing fluid over the top when running the inner- string inside the liner. A clean fluid supply should be used throughout the expansion process. 9. Make up the upper hanger joint assembly using a landing joint. Ensure proper precaution is taken to prevent damage to the external elastomer coating on the hanger when running it into the well. 10. Set the top of the liner as low as possible in the slips. This will allow the clearance required for a slip-on, or false table and maintain an acceptable working height. Record weight indicator reading. Precaution should be taken that the hole is protected to prevent items from being dropped either into the expandable liner or the annulus. 11. Rig down casing tongs and elevators. 12. Rig up 3-1/2 in. drillpipe elevators for running the inner-string. The rig tongs can be used to make up the inner-string. 13. Install the slip-on or false table for the drill pipe slips over top of the liner. 14. Rig up air or hand operated slips on top of the slip-on orfalse table. 15. Pick up and run workstring BHA. This inner-string BHA will consist of the following: 15.1. Safety sub - Acme (P) x 3-1/2 IF (B) .- Enventure-provided 15.2. One PUP joint 3-1/2 IF drill pipe - Rig-provided 15.3. Lower debris catcher - 3-1/2 IF (BxP) - Enventure-provided 15.4. Jars- 3-1/2 IF (BXP) Customer-provided This document contains information that is confidential and proprietary to EN VENTURE GLOBAL TECHNOLOGY and should not be disclosed to third parties without prior written permission from ENVENTURE GLOBAL TECHNOLOGY. Page 4 of 6 ,Chevron Alaska . . Cook Inlet #0-20 15.5. _joints 3-1/2 IF drillpipe - Customer-provided · NOTE: Install drillpipe wiper on first joint of 3-1/2 IF drillpipe. · NOTE: Strip taper guide onto string with connection sleeve before making up final joint of drillpipe. 16. Tag top of expansion cone assembly. Make up inner-string into safety sub box using the elevators with -10 turns and a maximum of 1,000 ft-Ib torque. 17. Remove airlhand operated slips and slip-on or false table. Clean threads and make up tapered guide with chain tongs. (record inner string weight) 18. Pick up on drillpipe and remove slips. Record weight indicator reading. 19. Continue in hole with 3 % IF drillpipe. Fill with clean fluid every _stands. 20. A high pressure hose will be rigged up on the derrick for expansion. 21. Run liner to setting depth using drill pipe tally, confirm depth with E-line, and record slackoff and pickup weights. · NOTE: All parties will agree that liner is on depth before initiating expansion. 22. Check to see that a mud bucket is rigged up and functional. During the expansion process the drillpipe will be full of fluid. 23. Conduct safety meeting and review procedure for expansion. Ensure that all necessary personnel are in radio communications with each other. An Enventure Project Manager will be on the rig floor and direct the expansion process. It is very important to capture the expansion parameters such as pressure, pump rate, and hook load. They will be recorded by Enventure PM during the expansion process. 24. Use 5 in. drill pipe pup joints to space out work string so that connection is close to floor level. 25. Rig up and test cement hard lines to 7,000 psii. NOTE: Verify working pressure of standpipe and pump lines before testing. · NOTE: The pump's rate and pressure must be visible on the rig floor near the driller's console during expansion operations. 26. With the cone face at the desired setting depth of the lower elastomer (Depth confirmed by E- line), begin pumping at 0.7 bbllmin with pump unit through the high-pressure lines and pressure up to rupture the burst disk in the expansion cone assembly. Burst disk pressure is -3,000 psi. 27. Continue pressuring up; expansion should begin at -3,850 psi. DO NOT EXCEED 4,200 psi. When expansion begins a decrease of the workstring weight will be noted on the weight indicator. Continue pumping at a rate of 0.7 to 2.0 bpm (20 to 30 ft/min expansion rate). Normal expansion pressure is expected to be -3,900 psi. After expansion of the hanger joint (-15 ft) stop pumping and release the pressure. Perform a pull test -15 to 20,000 lb. The expansion pressure maybe reduced by overpull after confirmation of lower anchor cladding. Volume required to expand one stand (based on stand length of 93 ft) excluding circulation and bypass is -5.6 bbls. This document contains information that is confidential and proprietary to ENVENTURE GLOBAL TECHNOLOGY and should not be disclosed to third parties without prior written permission from EN VENTURE GLOBAL TECHNOLOGY. Page 50f6 . Chevron Alaska . . Cook Inlet #D-20 28. Rig down cementing iron, layout pup joint (If used), rig up 2 in. high pressure hoses and pressure test to 5,000 psi. Begin pumping with -,7 bpm with 15 to 20,000 Ib overpull on string, Driller will start picking up on work-string when a reduction of string weight is indicated. 29. Expand the first joint until the tool joint is at an appropriate height to make a connection. Stop pumping and release pressure. Record flowback volumes on pumping unit. 30, Pump in at 1 bpm increase to 1.5 to 2 bpm at -2,000 psi and pressure up to continue expansion. Driller will continue picking up workstring when a drop of the weight is noted on the weight indicator, maintaining 10 to 20,000 Ib overpull on the blocks. Expand and pull workstring out by joints. 31. Tie elevators shut and continue expansion procedure until upper hanger joint begins to expand. After positive indication of cladding of the first elastomer section, pull an additional 40,000 Ib and reduce pump rate to 0.5 bpm. All nonessential personnel should leave rig floor. Continue this procedure through the remainder of the liner hanger joint until cone exit. 32. After the liner has been completely expanded, the well can be reversed out or circulated the long way and the liner top can be tested as per Chevron's specifications. . NOTE: Maximum test pressure on liner seal is 4,600 psi differential pressure. 33. Pull out of hole and lay down Enventure BHA. 34. The OD of the drill-out assembly should be accurately gauged to verify that it is compatible with the SET drift diameter. 35. Go in hole with drilling assembly. Take precaution when entering the top of the expanded liner. 35.1. If the bit sets down trying to enter or within the liner (-5,000 Ib), minimize weight and try to rotate through for a maximum of 5 minutes. . NOTE: Record all drill-out parameters for future reference. 35.2. If unsuccessful after 5 minutes, pull out of hole and review options for running a tapered mill and watermelon mill with smaller diameter than the bit. 36. Drill out float shoe. Circulate hole clean to remove aluminum debris from the hole. This document contains information that is confidential and proprietary to EN VENTURE GLOBAL TECHNOLOGY and should not be disclosed to third parties without prior written permission from ENVENTURE GLOBAL TECHNOLOGY. Page 6 of 6 RE: Dolly Varden D-20 Note a total of 80' of Expandable on Location - I am not 100' up to speed but the "Anchor Section" is "viton coated - One on each end - You start off by expanding 15' and then doing a pull test - They call the btm section the Anchor seal section and the top section is references an the liner hanger Joint - Both of these sections are expanded the same as the rest of the Expandable - Instructions reference a max differential rating of 4,600psi My comments on the Bullet summary are in Blue in the attached document along with Expandable info - All my phone numbers are attached do not hesitate to call (I miss Tyler) Evan K. Harness �v Drilling Superintendents' MidContinent Business Unit Chevron North America Exploration and Production 909 West 9th Avenue Anchorage, AK 99501 Office 907-263-7932 Office Fax 907-263-7884 or 907-263-7392 Cell 907-229-3592 Home 907 333-2228 eharness@chevron.com 1 of 1 12/21/2006 10:39 AM Re: Doll. Varden D-20 • • Evan, Some questions/requests: 1. Who is the engineering contact since Tyler is out until the New Year? 2. What does the timing look like? 2. Will you have two pipe ram bodies available, be changing rams or have VBRs in use? 3. We would appreciate your providing further information on the expandable pipe (burst, collapse, tensile, etc) and any packers/sealing hardware that will be employed. 4. Will the length of of the expandable be adjusted dependent on the results of the RTTS work? 5. What pressure value is to be used for testing the 9-5/8" casing and the ultimate repaired wellbore? Thanks in advance for the reply. Call or message with any questions. Tom Maunder, PE AOGCC Harness, Evan wrote, On 12/20/2006 11:20 AM: Tom Sorry for the late response 1) We will have 7" Rams available for the stack 2) We have elected to Move to Dolly Varden Well #20 as the First well in this campaign Evan K. Harness Drilling Superintendent *MidContinent Business Unit* *Chevron North America Exploration and Production* 909 West 9th Avenue Anchorage, AK 99501 Office 907-263-7932 Office Fax 907-263-7884 or 907-263-7392 Cell 907-229-3592 Home 907 333-2228 eharness@chevron.com 1 of 1 12/20/2006 12:15 PM Re: Chevron Well Work week of Dec 1 I -17 If I understand correctly, it is uncertain which well you will start with. The D-20 sundry says December 18. I have just started looking at the sundry and attachments. One thing I not is that it is proposed to use only 1 set of pipe rams. Since the surface pressure is likely less than 3000 psi, this would appear to be proper. From what I can see so far, you likely will need 7" rams when the casing is pulled. Do you have 7" rams available? Look forward to your reply. Tom Maunder, PE AOGCC Brandenburg, Tim C wrote, On 12/19/2006 7:55 AM: Tom, Please note that our current plan is to move to the Dolly Varden. We intend to work on D-20 and D-47. Currently we are awaiting equipment and are unsure as to which will be first. We anticipate knowing within the next two day's. I will let you know. We did submit a Sundry last week for the repair of D-20. If I don't speak to you, I hope you have a great holiday. Tim <<CVX Wellwork 06 I.xls>> of 1 12/20/2006 12:15 PM [Fwd: doly D-20 (169-095)] Subject: [Fwd: doly D-20 (169-095)] Date: Tue, 20 May 2003 16:08:33 -0800 From: Tom Maunder <tom_maunder~admin.state.ak.us> To: Jim Regg <jim_regg~admin.state.ak.us> Sorry, I did not include you on the original message. Tom Subject: doly D-20 (169-095) Date: Tue, 20 May 2003 16:08:02 -0800 From: Tom Maunder <tom_maunder~admin.state.ak.us> To: "Johnny Santiago," <santiagoj~unocal.com> CC: Dwight Johnson <johnsond~unocal.com> Johnny and Dwight. When an Inspector is out for safety valve tests, part Of the process is to record the various pressures on the wells tested. When Lou was out on May 15, he noted that the outer annulus pressure on D-20 was 900 psi. This pressure was 3 times greater than the next highest annulus pressure. The pressure conditions observed were: Tubing=120 psi, Gas Lift Annulus=1220 psi and Outer Annulus=900 psi. Would you please look into the reason for this pressure reading?? What is the pressure history of the OA on this well?? Is it bled from time to time?? Does it build back up?? Thanks in advance for your assistance with these questions. Please call with any questions. Tom Maunder, PE AOGCC Tom Maunder <tom maunder~admin.state.ak.'us> Sr. Petroleum Engineer Alaska Oil and Gas Conservation Commission I Sr. Petroleum E~tgrfig~T- --" ]Alaska Oil and Gas Conservation Commission 5/21/2003 11:16 AM MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: THRU: Dan Seamount, Commissioner ~ Blair Wondzell, P. I. Supervisor FROM: John Crisp? ~ ~. SUBJECT: Petroleum In~lziector DATE: June 22, 2000 Safety Valve Tests Dolly Varden Platform McArthur Rv. Field June 22, 2000: I traveled to Unocal's Dolly Varden Platform in the McArthur River Field to witness the Semi Annual Safety Valve System tests. Wells number 05, 17 & 31 Subsurface Safety valves were POOH for repair. Surface Safety valve on well 01 will be Changed out during next Platform shut down due to header valve leaks. The AOGCC test report is attached for failure reference. SUMMARY: I witnessed the Semi Annual SVS tests on the Dolly Varden P!_aff~.rm_ i n_ t.h_eMc~_h__u_~.R!y_~ r Fie Id. 24 wells, 57 components tested, 3 failures witnessed. 5.2% failure rate. Attachments: SVS Dolly Pit. 6-22-00jc cc; NON.CO~NFI~DE~NTIAL SVS Dolly Plt. 6-22-00jc MEMORAN TO: David Johr)~, Chairman"~~ ~ THRU: Blair wondzell, '/,._~'~' ~b0 FILE NO: P. I. Supervisor ~ FROM: Lou Grimaldi, Petroleum Inspector State' Alaska Alaska Oil and Gas Conservation Commission--' DATE: April 9, 1994 SUBJECT: 9VEJDHBD.DOC ~ _,~ , . I No Flow Verification -~ Wells #D-20,12,27,28,&25 Marathon Dolly Varden platform Middle Ground Shoal Field Friday, AI3ril 8, 1994: I traveled to Marathon's Dolly Varden platform in the Middle Ground Shoal field of Cook Inlet to verify the No Flow status of five wells. When I arrived the wells had already had their gas lift shut in and the tubing flowed down to the group separator, These were then flowed to the well clean system which has approximately .5 psi back pressure on it. The wells tubing was then routed to open top containers with water in them. All wells bled only gas and died off quickly with the exception of well #D-25 which kept flowing gas and would build up to 160 psi rath, er quickly, this may have been residual gas in the annulus coming through a leaky gas lift valve. The platform needed this well back for production and we did not attempt any further tests on other wells. Recommendations: Wells # D-20, D-12, D-27, and, D-28 exhibited a inability to flow from the formation without the assistance of artificial lift and met the criteria for No Flow status. Well # D-25 would not die off and should be maintained as a flowing well. Summary: I verified the no flow status of 4 wells on Marathon's Dolly Varden platform. cc: Don Lacour (Production Superintendent) Operator: Unocal Operator Rep: Mark Murietta AOGCC Rep: John Crisp ~ubmitted By: John Crisp Date: Field/Unit/Pad: McArthur Rv. / Dolly Varde Separator psi: LPS 110 HPS 6/22/00 .,: Well:~Datai~:~i~??:?., '~;~i,~:,.i?'.'.: i.!~ .-.;i-: Pil~'~'"~:: :;~i!!.:!',ii::.:':!?~::~'".) i'.',, i"i SV~'- .sS,. ;', ~" Well'.Type~::~:.- Well Permit Separ Set L/P Test Test Test Oil, WAC, OINJ, Number Number PSI PSI Trip Code Code Code GAS or CYCLE D-01 1670800 110 80 85 P 4 OIL , ,, D-02ARD 1750380 110 80 65 P 5 OIL D-03RD2 183081'0 110 80 80' P P OIL D-04RD 1820410 110 80 80 P P OIL , , D-05RD 1800650 110 80 100 P P 43 OIL · , , D-07RD2 1921550 110 80 80 P P P OIL D-08RD 1740030! 110! 80 75 e e e OIL D-11 1680730, 110, 80 80 P P P OIL D'-12RD 1800820, 110 80 75 P P 43 OIL D"- i'7RD 1810230 110 80 '" 80 P P 43 OIL D'- 18 1690040 800 700 700 P P P GAS D~20~ ~ ~' 1'690950 110 '80 90 P P OIL D'-25RD ' 1780870 110 80 100 ' P e OIL D-26RD 1981290 110 80 " 75 e P " OIL D-27 1750240 110 -80I' 60 e P ' OIL , D-28 1760360 110 80' 100 P P ' OIL D-30RD2 1880980 ~ ' ' D-3iRD '" 1760740 110 80 70 P' P 43 ~ OIL D-32 1700370 110 80 75 P P P OIL D-40RD 1'820830 110 80 80 e e' oil D-42 1830530 110 80 70 P P OIL ....... , , D-43RD 1853110 110 80 70 P P P OIL ....... D-46 1890610 110 80 60 P P P OIL , ,, D-47 1910110 110 80 70 P P 9 OIL , D-48 1921540 110 80 80 P ,P P OIL , , Wells: 24 Components: 57 Failures: 3 Failure Rate: 5.2% ID 90 Day Remarks: Wells that have SSSVs out for repair are designated 43 & not counted as failures or components tested. 6/27/00 Page 1 of 1 SVS Dolly Plt. 6-22-00jcl Unocal North Ame~'~' ': 011 & Gas Division ~ Unocal Corporation 909 West 9th Ave., P.O. Box 190247 Anchorage. Alaska 99519-0247 Telephone (907} 276-7600 Alaska Region UNOCAL DOCUMENT TRANSMITTAL APR 2. 0 199) Alaska 0il & Gas Cons. Commission April 16, 1993 TO: Larry Grant FROM: Kirk Kiloh LOCATION: 3001 PORCUPINE DRIVE LOCATION: P.O.BOX 196247 ANCHORAGE, AK 99501 ANCHORAGE AK 99519 ALASKA OIL & GAS CONSERVATION COMM. UNOCAL" ...... - _ -- __: - ,,,, tI , __, .,,,ll, _ ,LiII,_ __ Il _ II ,, ,, __ LIJ, , lill, _LJ tIIJIJLL_J U__ L , _, ...... ' TRANSMITTING AS FOLLOWS ' TRADING BAY UNIT 1 blueline and 1 sepia Logs from specified wells listed below 5~0-~ .- D-SRD 7 7--~7-- -- D-7RD ~[..&,-~ -,D-17RD ~D-20 Perforating Record Perforating Record Perforating Record 'Perforating Record · Perforating Record .Perforating Record Completion Record Completion Record 10-18-92 10-19-92 11-30-92 11-22-92 11-29-92 12-04-92 6-29-92 6-16-92 Perforating Recoza 11-21-92 Perforating Record 11-25-92 Perforating Record Perforating Record Perforating Record Continuous Gyro Tool Cement Bond Tool Perforating Depth Control 10-17-92 12-03-92 12-18-92 7-24-92 7-24-92 8-12-92 M-29 Tubing Patch Record 11-13-92 PLEASE,ACKNOWi.EDGE REC~ BY SIGNING AND~TURNING ONE COPY OF DATED: ( STATE OF ALASKA COM (~ ~ONMi5;~ A~,oKA OIL AND GAS CONSERVATION REPORT OF SUNDRY WELL.OPERATIONS 1. Operations performed: Operation shutdown ~ Stimulate ~ Plugging m Perforate )[_... Pull tubing ~ Alter casing ~ Repair well ~ 2. Name of Operator ! 5. Type';3f Well: UNOCAL (Marathon Oi 1 Co - Sub Operator) Development ~ Exploratory __ 3. Address Stratigraphic ~ P. Oo Box 190247 Anchorage, AK 9951~ Se~cew 4- L°cati°n °f we" at sudace Leg B-1 Cond. #4, Dolly Varden Platform 672' FSL, 1,211' FWL, Sec. 6- 8N- 13W- SM At top of productive interval 2,072' FNL, 2,035' FWL, Sec. 6- 8N- 13W- SM At effective depth At total depth 1,884' FNL, 2,163' Other 6. Datum elevation (DF or KB) 106' KB above MSL feet · 7. Unit or Property name Trading Bay Unit FWL, Sec. 6- 8N- 13W- SM 8. Well numDer D-20 9. Permit number/approval number 69-95/92-177 ... 10. APl number 5o-7-33-20203 11. Field/Pool Hemlock 12. Present well condition summary Total depth: measured true vertical 10,506 ' feet Plugs (measured) 10,027' feet Effective depth: measured 10,430 ' feet Junk (measured) true vertical 09,95 5 ' feet Baker "D" Pkr w/Otis Q Nipple & Muleshoe 10,198' - 10,212' Casing Length Size Cemented Measured depth Structural Conductor Sudace 3,006' 13-3/8" 2,400 sx 3,006' Intermediate 9,674' 9-5/8" 2,900 sx 9,674' Production 1,017' 7" 300 sx 10,480' Liner Perforation depth: measured True vertical depth true vertical See Attachment #1 Tubing (size, grade, and measured depth) 3-1/2" 9.2# N-80 BUtt. Tbg e 9,644' Packers and SSSV (tvpe and measured deDth) Otis 3-1/2" DC TBRU 2.75" ID 0 328' Baker FB-1 Pkr, 4.0" ID w/10' SBE @ 9,592'; Baker"D" 3.25" ID 13. Stimulation or cement squeeze summary 14. Intervals treated (measured) Treatment description including volumes used and final pressure Prior to well operation Alaska Oil & ~a$ ~Jons. fi_ej~ Representati~ D~ly A~mge Pr~u~on or Injection Da~ Subsequent to operation 15. Attachments Copies of Logs and Surveys run .._.. Daily Report of Well Operations X Oil ~ Gas ~ 17, I hereby certify that the foregoing is true and correct to the best of my knowledge, OiI,Bbl Gas-Md Water-Bbl Casing Pressure Tubing Pressure 329 ~ ...... 56 1037 1160 140 359 / 217 996 1150 140 . , 16. Status of well classification as: Signed Form 10-404 ~v.~/l~ Suspended ~ Service SUBMIT IN DUPLICATE Attachment #1 TBU Well D-20 Perforations Bench MD TVD I 9,820' - 9,865' 9,378' - 9,458' 3 9,865' - 9,885' 9,458' - 9,501' 3 9,905' - 9,950' 9,501' - 9,609' 4 9,950' - 10,065' 9,609' - 9,633' 5 10,090' - 10,190' 9,633' - 9,727' 6 Below Plug 10,230' - 10,260' 9,764' - 9,793' 71/DVP2 DALLY I~ELL OPERATZONS D-20 6/15/92 RU SWS. Safety meeting. Psi test lubricator to 2500 psi. Good Test. Establish C80. Ann 30' 2-1/8" strip guns 4SPF, 0° phase. RIH w/guns. Perforate the following intervals: Run #1 HB-3 9905' - 9935' DIL Fired Run #2 H8-1,3 9855' - 9885' DIL Fired Run #3 HB-1 9825' - 9855' DIL Fired RD SWS. Return we~ to production. H: \wp\WE L LOPS\D20 ('~ STATE OF ALASKA S~. ALASKA OIL AND GAS CONSERVATIONCOMM' iON 0 R ! G I N A [ ~ APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon __ Suspend __ Alter casing __ Repair well __ Change approved program __ Pull tubing __ Variance __ 2. Name of Operator J 5. Type of Well: UNOCAL (Marathon Oi ] Co guh nn~_rnt.inr)/ Development ~ - Exploratory __ 3. Address AK' 99~ Stratigraphic__ P. O. Box 190247 Anchoraqe, 9 Service__ 4. Location of well at surface Leg B-1 Cond. #4, Dolly Varden Platform Operation shutdown __ Re-enter suspended well __ Plugging __ Time extens, on __ Stimulate __ Perforate ~ Other __ 6. Datum elevation (DF or KB) 7. Unit or Property name 8. Well number feet 672' FSL, 1,211' FWL Sec. 6- 8N- 13W- SM At top of productive interval ' 2,072' FNL, 2,035' FWL, Sec. 6- 8N- 13W- SM At effective depth At total depth 1,884' FNL, 2,163' FWL, Sec. 6 - 8N - 13W - SM 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length Structural Conductor Sudace 3,006' Intermediate 9,674 ' Production 1,017' Liner Perforation depth: measured 10,506' feet Plugs (measured) 10,0 2 7' feet 10,430' feet Junk(measured) 9,955' feet Size Cemented ~.-I:¢%Ym it number 1~. A'~'r Number 11. Field/Pool Hemlock Baker' "D" Pkr w/Otis Nipple & Muleshoe 10,198' - 10,212' Tagged fill @ 10,159' WLM Measure~d~th True vertical depth 13-3/8" 2,400 sx 3,006' 9-5/8" 2,900 sx 9,674' 7" 300 sx 10,480' RE6EIVED true vertical See Attachment #1 d u L - 6 1992 Alaska Oil & Gas Cons. Commis$i~ Anchorage Tubing (size, grade, and measured depth) 3-1/2" 9°2# N-80 Butt. Tbg ¢ 9,644' Packers and SSSV (type and measured depth) Otis 3-1/2" DC TBRU 2.75" ID ¢ 328' I II II II Baker FB-1 Pkr. 4.0" ID w/lO' SRF 0 13. Attachments Description summary of proPosal __' D6tailed operations I~rOc~r~m X_..~ - -B-d#~k~tch __X 14. Estimated date for commencing operation 6/14/92 16. If proposal was verbally approved Name of approver Mike Mender 6/12/92 Date approved 15. Status of well clasSification as: Oil ..~ Gas __ Suspended __ Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed (~ ~_~-,-.k ~, ~"~ ~ (~p ~ FOR COMMISSION USE ONLY "~ Conditions of roval: Notify Commission so representative may witness Plug integrity __ BOP Test __ Location clearance __ Mechanical Integrity Test __ Subsequent form required 10- ',Ft..a,~F' Date !ApprOval NO' Approved Copy Returned Approved by order of the Commission .(~rlglnal Signed By David Wo Johnston ,q- 2J- q2 Commissioner SUBMIT IN TRIPLICATE Form 10-403 Rev 06/15/88 Attachment #1 TBU Wel 1 D-20 Perforations Bench MD TVD i 9,820' - 9,865' 9,378' - 9,458' 3 9,865' - 9,885' 9,458' - 9,501' 3 9,905' - 9,950' 9,501' - 9,609' 4 9,950' - 10,065' 9,609' - 9,633' 5 10,090' - 10,190' 9,633' - 9,727' 6 Below Plug 10,230' - 10,260' 9,764' - 9,793' 71/DVP2 TBU UELL D-20 . . e . e ge 10. 11. RU wireline unit (No rig skid required - Leg B-l). Sheave to be hung off crane. Hook up platform communication system in unit. Pressure test lubricator &~ BO__._PE_to 2500 psi ... ___ Apply 4000 psi control line pressure to the SCSSV using the auxiliary pump. Monitor for any pressure leak off prior to RIH. RIH w/ 2.35" broach. Increase broach sizes in an attempt to clear tubing to at least 2.40". If scale removal is proceeding well, open up to 2.50" using broaches in increments of approximately 0.05" - 0.10". POOH. RD wi reline. Obtain a 24-hour well test. RU E-line unit. No rig skid required (Leg B-l). Sheave to be hung off crane. Hookup platform communication system in unit. Pressure test lubricator & BOPE to 2500 psi. Apply 4000 psi control line pressure to the SCSSV using the auxiliary pump and monitor for any leak off prior to RIH. RIH 2/2-1/8" strip guns, 4 SPF, 0 degree phase, and perforate the following intervals underbalanced: RUN BENCH INTERNAL (DIC) FOOTAGE i 3 9,905' - 9,935' 30' 2 1/3 9,855' - 9,885' 30' 3 I 9,835' - 9,855' 30' 90' RD E-line unit. Return well to production and obtain a 24-hour well test cleanup. H:\wp\wLpro.D20 RECEIVED J U L - 6 1992 Alaska Oil & Gas Cons. bommissm,. Anchorage TBU WELL D-20 COMPLETION SCI1EMATI~ {Completed 12/83 Cement Squeeze tlole 1497 '2? 29~ N-80 8 Rd o' ~723 LT & C W/ TIW LH packer 13-3/8" 61# K-55 ASL 3006 ClW 4-1/2" EUE 8Rd x Butt tubing hang~ 328 3-1/2" Otis DK WLRBV ~ ID Completion String: 3-1/2" 9.2#, N-80 5utt. Tbg @9,644' 24~7 GLM #1, 3-1/2" Camco KBUG, 2.75" ID, w/ Camco 1.0" BK Valve, BK-2 latch 9-5/8" 40, 43.5, 47# N-80, $-95 Butt & 47# AR-95 ASL -4311 GLM #2 5637 GLM #3 6766 GLM #4 9463 '-Baker FB-1 Packer, 4.0" ID, w/10 ft SBE & bellguide ~ ~92' DIL (9601' tbg). . 9674 7" 29f! N-80 X-Line fill tagged at lO,062"WLM 1'f'89 7563 GLH #5 8184 GLH #6 8621 GLH #7 8944 GLH #8 · ~147 GLH /~9 · :: 9599 Baker Locator, 14 ft. 4" x 3" seal 9644 Baker half-cut mule shoe 2.94" ID DIL Depths 9820 - 9865 Bench 1 .. 9865 - 9885 Bench 3 9905 - 9950 Bench 3 . 9950 - 10,065 Bench 4 10,068 .Baker Hodel D Packer 3.25" ID '10,O78 Otis X Nipple 2.75" ID 10,086 Bell Guide 3.00" ID Tagged Fill @ 10,159' WLM 2/88 Note: 6hable to work 2-1/16" tbg into packer during workover November, 1983 10,090 - 10,190 Bench 5 10,198 10,206 10,212 Baker Hodel D Packer 3.25" ID Otis Q Nipple 2.625" ID Mule Shoe 10,230- 10,260 Bench 6 PBTD 10,430 TD 10,506 . YLRO 2/89 (,)OLLY VARDEN P~'ATFORM Wireline Lubricator w/Associated BOPE , GREASE HEAD (Hydraulically Activated) LUBRICATOR MANUALLY OPERATED BOP 4' ~1/.'1.6~. '5 O0 0 psi CHISTMAS TREE POSITIVE CHOKE ----- 2' 5000 psi ][---- 2' 3000 psi 13 3/8' CASING Unocal North Amer~~~ Oil & Gas Division ~ Unocal Corporation P.O. Box 190247 Anchorage, Alaska 99519-0247 Telephone (907) 276-7600 UNOCAL, Alaska Region April 16, 1990 Alaska Oil & Gas Conservation Commission 3001 Porcupine Dr. Anchorage, AK 99504 Attn: Ms. Elaine Johnson Dear Ms. Johnson. I have attached surface survey locations of the "Legs" and conductors for the four platforms in the Trading Bay Unit as well as the Union Oil-operated Monopod and Granite Point Platforms. I was unable to locate any plats from a registered surveyor but I hope this will meet your needs. Yours very truly, a~ S.~~u~ ~~~ sh ' l~eg~.onal Drilling Manager GSB/lew DOLLY DISTANCE & DIRECTIONS .FROM SE CORNER SEC. 6, TSN, R13W ,,, CONDUCTOR LEG #A-1: LAT = 60o48, 28.272" LONG :151°37' 57.620" "Y" COORD. "X" COORD. WELL # 2,490,836.22 208,461.20 FSL 757.5 2,490,836.95 208,454.55 D-27 2,490,840.99 208,456.66 D-28 2,490,842.79 208,460.79 D-29 2,490,841.51 208,465.11' 'D-32 · 2,490,837.76 208,467.60 D-40 2,490,833.28. 208,467.10 D-41 2,490,830.18 208,463.83 D-26 2,490,829.90 208,459.34 D-25 & RD 2,490,832.58 208,455.72 2,490,835.56 208,458.66 D-24 & 34A 2,490,838.66 208,462.17 D-31 & RD 2,490,834.00 208,462.61 D-24A LEG #A-2' 2,490,835.42 208,381.20 2,490,836.16 208,374.66 . D-1 2,490,840.19 208,376.67 D-17 2,490,842.00 208,380.80 D-11 2,490,840.72 208,385.11 D-7 & RD 2,490,836.97 208,387.60 D-9 2,490,832.49 208,387.10 D-19 2,490,829.39 208,383.84 D-23 2,490,829.11 208,379.34 D-21 2,490,831.78 208,375.72 ' D-5 & RD '2,490,834.77 208,378.66 D-15 & RD .& 2 2,490,837.86 208,382.17 D-3 & RD 2,490,833.21 208,382.61 D-13 758.1 762.1 764.0 762.9 759.2 754.7 751.5 751'.1 753.7 756.8 760.0 755.3 754.7 755.3 759.4 761.3 760.1 756.4 751.9 748.8 748.4 750.9 754.0 757.2 752.5 LEG ,B-l' LAT = 60048' 27.485" LONG =151037' 57.564" 2,490,756.22 208,462. O0 677.5 1 2 3 4' 5 6 8 9 0 1 2 2,490,755.48 208,468.53 D-8 & RD 2,490,751.45 208,466.53 D-6 2,490,749.65' 208,462.40 D-14 & RD 2,490,750.92 208,458.08 D-20 2,490,754.67 208,455.59 D-16 2,490,759.15 208,456.10 D-22 2,490,762.25 208,459.36 D-2 & A & RD 2,490,762.53 208,463.85 D-4 2,490,759.86 208,467.48 D-10 2,490,756.87 208,464.53 D-12 & RD 2,490,753.78 208,461.02 D-18 2,490,758.43 208,460.58 D-30 & RD 677.0 672.9 671.0 672.1 675.8 680.3 683.5 683.9 681.3 678.3 675.1 679.7 LEG #B-2: 2,490,755.43 208,382. O0 (Reserved for Compressors) 674.8 FWL 1212.0 1205.5 1207.4 1211.5 1215.8 1218.4 1218.0 1'214.8 1210.3 1206.7 1209.5 1213.0 1213.5 1132.1 1125.5 1127.4 1131.5 1135.9 1138.5 1138.1 1134.9 1130.4 1126.7 1129.6 1133.0 1133.6 1214.8 1221.4 1219.5 1215.4 1211,.1 1208.5 1208.9 1212.1 1216.5 1220.2 1217.4 1213.9 1213.4 1134.9 LA( STATE OF ALASKA ~,N' A . .A OIL AND GAS CONSERVATION COMMIS REPOFR' OF SUNDRY WELL OPEF TION$ 1. Operations performed: Operation shutdown __ Stimulate __ Plugging __ Perforate Pull tubing __ Alter casing __ Repair well ~ Pull tubing __ 2. Name of Operator ! 5. Type of Well: UNOCAL (Marathon Oil Co - Sub OperAtor) Devel.opm.entx ! Exlmora[ory __ 3. Address | Stratigraphic __ P. O. Box 190247 Anchorage, AK 9~519 Service__ 4. Location of well at sudace Leg B-1 Cond. #4, Dolly Varden Platform 672' FSL, 1,211' FWL, Sec. 6 - 8N- 13W- SM At top of productive interval 2,072' FNL, 2,035' FWL, Sec. 6- 8N- 13W- SM At effective depth At total depth 1,884' FNL, 2,163' FWL, Sec. 6 - 8N - 13W- SM 12. Present well condition summary Total depth: measured 10,506 ' feet Plugs(measured) true vertical 10,0 2 7 ' feet 'Effective depth: measured 10,430 ' feet Junk (measured) Other __ Datum elevation (DF or KB) 106' KB above MSL Unit or Prope_rty name Trading Bay Unit 8. Well number D-20 9. Permit number/approval number 8-650 -10. APl number 50-- 733-20203 11.' Field/Pool Hemlock Baker "D" Pkr w/Otis Q Nipple & Muleshoe 10,198' - 10,212' true vertical 9,95 5 ' feet Casing Length Size Cemented Structural feet Tagged fill @ 10,159' WLM 2/88 Measured depth True vertical depth Conductor Surface - 3,006' 13-3/8" Intermediate 9,6 7 4 ' 9- 5 / 8" 2,400 sx 2,900 sx 3,006' 9,674' Production 1,017' Liner Perforation depth: measured 7I! 300 sx 10,480' RECEIVED true vertical ~bing(size, grade, and measumddepth) 3-1/2" 9.2# N-80 Butt. Tbg @ Pac~mandSSSV(typeandmeasumddeCh) Baker FB-1Pkr, 4.0" ID w/10' See 9,644' SBE Attachment #1 JAN 1 7 1989 Naslm I ii & Gas oral ." Otis 3-1/2" DC TBRU 2.75" ID @ 328' @ 9,592'; Baker "D" 3,25" ID @ 10,068' 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure 14. Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 8/25/88 377 333 828 1210 160 Subsequent to operation 9/14/88 462 270 1148 1145 15. Attachment~¢ ¢f2 116. Status of well classification as: Copies of Logs and Surveys run __ I Daily Report of Well Operations ~x Oil x__ Gas __ SuSpended- 17. I hereby certify that the foreg'~)ing is true and correct to the best of my knowledge. I Signeted· ¢R~°b~rt~s~'~ Title-Environmental Engineer Service 140 Date 1/9/89 Form 10-404 Rev 06/15/88 SUBMIT IN DUPLICATE Attachment #1 TBU Well D-20 Perforations Bench MD TVD 1 9,820' - 9,865' 9,378' - 9,458' 3 9,865' - 9,885' 9,458' - 9,501' 3 9,905' - 9,950' 9,501' - 9,609' 4 9,950' - 10,065' 9,609' - 9,633' 5 10,090' - 10,190' 9,633' - 9,727' 6 Below Plug 10,230' - 10,260' 9,764' - 9,793' 71/DVP2 Attachment #2 TBU Well D-20 Daily Summary of Well Operations 8~28~88 RU E-line and PT to 2500 psi, OK. SI well and made two perforating runs using 2-1/8" Enerjet II, 4 SPF, 0° phasing, 13.5 gm charge perforating guns. Correlate and perforate Bench 4 from 9970' to 9990' and 9950' to 9970' DIL. Flowed well for 15 min. after each perforating run. 8/29/88 Made two perforating runs using same guns as before. Correlated and perforated Bench 3 from 9905' to 9935' and 9865' to 9885' DIL. Flowed well for 10 min. after each perforating run. POH, RD, and put well in test. 8/3o/88 RU E-line and PT to 2500 psi, OK. Made two perforating runs using Enerjet II guns as before. Correlated and perforated Bench 1 from 9835' to 9865' and 9825' to 9835' DIL. Flowed well for 10 min. after each perforating run. Tagged bottom @ 10,050' WLM. POH, bring well on slowly and put in test. The proposed scale inhibition treatment was not performed at this time. 71/DVP2 STATE OF ALASKA ALA A OIL AND GAS CONSERVATION COM ,$SION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon Suspend . ' Operation Shutdown ~ ~ Re-enter suspended well ~ Alter cas,ng rj; T,me extension Change approved program Plugging '~ Stimulate .~ Pull tubing Amend order ,r Perforate _~. Other 2 Name of Operator UNOCAL (Marathon Oil Company - Sub Operator) 3 Address P. O. Box 190247 Anchorage, AK 99519 4. Location of well at surfaceLeg B-1 Cond. #4, Dolly Varden Platfor~ 672' FSL, 1,211' FWL, Sec. 6 - 8N - 13W- SM At top of productive ~nterval 2,072' FNL, 2,035' FWL, Sec. 6 - 8N - 13W- SM At effective depth At total depth 1,884' FNL, 2,163' FWL, Sec. 6- 8N- 13W- SM 5. Datum elevation (DF or KB) 106' KB above MSL 6. U_nit of,Prop~,rty name_ · l'raa3-ng ~ay un3. c 7. Well number D-20 8. Permit number 69-95 9. APl number 50-- 733-20203 10. Pool · Hemlock 11. Present well condition summary Total depth: measured true vertical 10,506' feet 10,027' feet Effective depth: measured 10,430' true vertical 9,955 ' Casing Length Structural Size feet feet Plugs (measured) Junk (measured) Cemented Baker "D" ?kr w/Otis Q Nipple & Muleshoe 10,198' - 10,212' Tagged fill @ 10,159' WLM 2188 Measured depth True Vertical depth Conductor Surface 3,006' Intermediate 9,674' Production Liner 1,017 ' Perforation depth: measured 13-3/8" 9-5/8" 2,400 sx 2,900 sx 7" 300 sx true vertical Tubing (size, grade and measured depth) See Attachment #1 3,006' 9,674' 3-1/2" 9.2# N-80 Butt. Tbg @ 9,644' Packers and SSSV(type and measured depth) Otis 3-1/2" DC TBRU 2.75" ID @ 328' Baker FB-1Pkr, 4.0" ID w/10' SBE @ 9,592'; Baker "D" 3.25" ID @ 10,068' 12.Attachmentx 2 & 3 Description summary of proposal _x! Detailed operations program C_.; BOP sketch 13. Estimated date for commencing operation August 1988 14. If proposal was verbally Name of approver Date approved 15. I hereby ce t~at the foregoing is true and correct to the best of my knowledge /R~z" D. Roberts:' Commission Use Only Conditions of approval Approved by Date 8/23/88 N~otify commission so representative may witness I Approval No. Plug integrity ~ BOP Test ~ Location clearance Approved Copy Ol]~ SIGNED BY Returned ~L0~ C, SMffM - ~.-~ '~'~' by order of ' :~i:!~' Commissioner the commission Date feet Form 10-403 Rev 12-1-85 Submit in triplicate Attachment #1 TBU Well D-20 Perforations Bench MD TVD 1 9,820' - 9,865' 3 9,865' - 9,885' 3 9,905' - 9,950' 4 9,950' - 10,065' 5 10,090' - 10,190' 6 Below Plug 10,230' - 10,260' 9,378' - 9,458' 9,458' - 9,501' 9,501' - 9,609' 9,609' - 9,633' 9,633' - 9,727' 9,764' - 9,793' Attachment # 2 Well D-20 Reperf/Scale Inhibition Treatment Procedure A. Perforate 1. RU WL. PT to 2500 psi. 2. RIH w/ 2.70 gauge ring and tag bottom. POH. 4. RU E-line. PT to 2500 psi. 5. Perforate the following intervals w/ 2-5/8" hollow carrier guns, 4 SPF, 0° phase angle, and 500 psi drawdown: Run Interval (DIL) Feet Zone 1 9,970' - 9,990' 20 Bench 4 2 9,950' - 9,970' 20 Bench 4 3 9,910' - 9,940' 30 L. Bench 3 4 9,865' - 9,885' 20 U. Bench 3 Test well for 12 hours after stabilized, continue perforating if total oil rate is less than 600 BOPD. 5 10,150' - 10,180' 30 Bench 5 6 10,120' - 10,150' 30 Bench 5 7 10,095' - 10,120' 25 Bench 5 8 9,845' - 9,865' 20 Bench 1 9 9,825' - 9,845' 20 Bench 1 6. RD E-line. Note: Bring well on slowly and obtain a stabilized production test. Produce well for 3 days prior to placing D-20 on a scale inhibition program. B. Scale Inhibition Treatment 1. RU pumping equipment to D-20 tree. PT to 5000 psi. 2. Mix and pump scale inhibitor as follows: Stage 1. Stage 2. Stage 3. Stage 4. Stage 5. 50 bbl FIW (established injection rate) 52 bbl FIW w/2.5% phosphonate preflush (55 gal Scaletreat 194/4) 25 bbl FIW (spacer) 175 bbl FIW containing 1750 lbs of sodium chloride w/ 10% inhibitor (770 gal Scaletreat ESL 19P) 900 bbl FIW overflush Attachment # 2 Well D-20 Reperf/Scale Inhibition Treatment Procedure (Continued) Treatment to be pumped at 2 BPM max. Surface pressure to be kept below 3000 psi to avoid fracturing the reservoir. 3. RD pumping equipment and shut in D-20 for 24 hours. 4. Bring well on slowly to test. Start lift gas at lowest rate necessary to lift well. Work up to a full lift gas rate of 3.1MMSCFD over a 24 hour period. 5. A Western Wellchem engineer will take fluid samples hourly for the first 24 hours to monitor residuals. Two to four samples will be taken for the remainder of the week. After one week, samples will be taken once a week for the remainder of the month. After one month, a fluid sample should be taken monthly and sent to Wayne Cissell. 6. A gauge ring will be run every three to four months to monitor inhibitor effectiveness. Note: Maximum anticipated bottomhole pressure is 3500 psi. em/837/OE33 Attachment #3 i~JLLY VARDEN PLA(' FORM Wireline Lubricator w/Associated BOPE MANUALLY OPERATED BOP GREASE HEAD (Hydraulically Activated) LUBRICATOR 3 1/8'. 5000 psi CHISTMAS TREE POSITIVE CHOKE .~---- 2' 5000 psi .------ 13 3/8' CASING STATE OF ALASKA ALASKA(~" ~_ AND GAS CONSERVATION C~ MISSION SUNDRY NOTICES AND REPORTS' ON WELLS 1. DRILLING WELL [] COMPLETED WELL OTHER [] 2. N_i~m,, of Oper_ato~; 7. Permit No. unzon uzl Company of California * 69-95 3. Address 8. APl Number P.O. Box 6247, Anchorage, Alaska 99502 50_733-20203 4. Location of Well Surface: Leg B-i, Cond. 94, Dolly Varden Platform 672' FSL, 1211' FWL, Sec. 6-T8N-R13W-SM 5. Elevation in feet (indicate KB, DF, etc.) 106' KB above MSL 6. Lease Designation and Serial No. ADL-18729 9. Unit or Lease Name Trading Bay Unit 10. Well Number D-20 WO 11. Field and Pool McAr thur River Field 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 E~ Altering Casing [] Stimulate [] Abandon [] Stimulation [] Abandonment [] Repair Well [] Change Plans [] Repairs Made [~ Other [] Pull Tubing [] Other [] Pulling Tubing ' [~J (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). Workover 1983. See the operations began November 8, 1983, and were completed December 8, attachment for a record of operations. JAN 0 1.984 0ii & Gas Cons. Commission Anchorage * Marathon Oil Company -- Sub-Operator 14. I here ~fy that the fore ' g i e and c rrect to t e best of my knowledge. Signed le Dist. Drlg. i/~w w- · . ~v~w ...... Th~l~a~elow for Commission use C donjons of Approval, if any: Date/~e~mber 28,]983 Superintendent Approved by. By Order of COMMISSIONER the Commission Date Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate .. · · Attachment Well D-20 WO was completed as follows: 1. Rigged up on Well D-20 and pulled SSSV. 2. Rigged up and perfed tbg @ 9,294'-9,296' MD w/ 8 HPF. 3. Pumped FIW down tbg. No communication to annulus. 4. Killed well by reverse circ through gas lift valves. 5. Set BPV. ND X-mas tree, NU BOPE. 6. Pulled tbg loose. Could not circulate. Tubing plugged. 7. Rigged up and perfed tbg @ 7,504'-7,506' MD w/ 4 HPF. Circ FIW around. 8. POH & LD 4-1/2" & 3-1/2" production tbg. 9. Tested scab liner, OK. 10. Ran GR/JB/CCL. ll..Set isolation pkr @ 10,068' DIL, and production pkr @ 9,592' DIL. 12. RIH w/ 3-1/2" production tbg. 13. Set BPV. ND BOPE, NU Xmas tree. 14. Returned well to production. Prod before WO: 751 BFPD, 353 BOPD, 53% WC, 398 BWPD Prod after WO: 1402 BFPD, 544 BOPD, 64% WC, 858 BWPD 15. Reperfed .as follows: Bench 3 - 9,905'-9,937' DIL. Bench 4 - 9,950'-9,982' DIL. 10,032'-10,064' DIL, 4 HPF,0 phasing, under drawdown. Prod after reperf: 1798 BFPD, 756 BOPD, 58% WC, 1042 BWPD STATE OF ALASKA ALASKA LANDGAS CONSERVATION C ~vlMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL ~ OTHER [] 2. Name of Operator 7. Permit No. Union Oil Company of California* 69-95 3. Address 8. APl Number P.O. Box 6247, Anchorage, Alaska 99502 5o- 733-20203 4. Location of Well Surface: Leg B-l, Cond #4, Dolly Varden Platform 672'FSL, 1211'FWL, Sec. 6-8N-13W-SM 5. Elevation in feet (indicate KB, DF, etc.) 106I KB above MSI 12. 6. Lease Designation and Serial No. ADL-18729 9. Unit or Lease Name Tradinq Bay Unit 10. Well Number D-20 11. Field and Pool McArthur River Field 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 )f[~ 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 s~tate all pertinent details and give pertinent dates, including estimated date of starting any -. ' proposed work, for Abandonment see 20 AAC 25.105-170). Workover Well D-20 Procedure: .. 3. 4. 5. 6. 7. 8. Move Rig 76 over D-20 and rig up. Kill well, install BPV, remove tree, Pull 4 1/2'l and 3 1/2'l tubing. R IH w/ bit and scraper. Set isolation packer above B-5. Set production packer ~ Hemlock. RIH w/ 3 1/2" production tubing w/ GLV. Install BPV, remove BOPE, install and test tree. Return the.~',Well 'to production. Reperforate and treat as required. install and test BOPE. RE E VED Sul-~seque~t Wo;k ~e?,orted FEB -, ? 1983 Alaska 0il & Gas Cons, C0mmJs~i0,~ AnChorage *Marathon Oil Company Sub-operator 14. I he/~ertifY ,~h~/~e~/~g is true and correct to the best of my knowledge.//~ Signed(//.//.~-~ ~.//.~¢.~~.....~-~"~ Title DIST DRLG SUPT The s~/~below fo r C~m mission us~e~/'~,- ~,,ions of ApproCa,, if any: Approved Copy Returned 'ORIGINAL SIGNED ~.~ BY LONNIE C. SMITH By Order of Approved by COMMISSIONER the Commission Date 2/3/83 Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate Union Oil and Gas ~ion: Western Region ,, Union Oil Company of California P.O. Box 6247, Anchorage, Alaska 99502 Telephone: (907) 279-7681 unlln September 26, 1975 Mr. Tom Marshall Division of Oil & Gas State of Alaska o u.ine Anchorage, Alaska 99504 RE: TBUS D-20 (22X-6) Dear Mr. Marshall: Enclosed for your files are tWo (2) coPies of the Sundry Notice & Reports on Wells for the above captioned workover, Very truly yours, District Drlg. Supt. sk Encl. (2) cc: Marathon Oil Co. Atlantic Richfield Co. Amoco Production Co. Phillips Petroleum Co. Skelly Oil Co. Standard Oil Co. USGS - Mr. Rodney Smith : .- ~.~V. ~3-30-69 ' & "Su~quent ~po~s" m Dupli~te ; OIL AND GAS CONSERVATIO.N CO:~I~EE (Do not use this form for proposals to drill or to deepen Use "APP-L, ICATION 'FOR ~'EI~I~IT-L~' 'for such 'p~o~oaal$.) . . WELL WELL OTHER 2. NA.ME OF OPERATOR *Union Oil Ccxapany of California 3. ADDRESS OF OPERATOR 909 ~st Ninth Avenue, _Anchorage, Ak. 99501 4. LOCATION OF WELL At~urface 672.1' FSL & 1211.1' FWL of Sec. 6, T.EN, R13W, SM, Cond. #4, SE leg, Dolly Varden At Hemlock top: 2072' FNL & 2035' ~4L of Sec. 6 13. ELEVATIONS (Show whether DF, RT, GR, etc. KB- 106 Check Appropriate Box To I,ndicate Niature of NOtice, Re ~. AP1 NUME, RICAL CODE 50-133-20203 6. LEASE DESIGNATION A/~D SERIA3~ NO. ADL-18729 ?. IF INDIA~, ALLOTTEE OR TH/BE HA/ViE 8. UNIT, FA.RAi OR LEASE NAME · Trading Bay Unit 9. WELL NO. D-20 (22x-6) 10. FT~T!) AiYD POOL, OR WILDCAT McArthur River Field-Hemlock 11. SEC., T., R., M., (BOTTOM HOLE OBJECTIVE) Sec. 6. TBN. R13W. SM ' 12. PER1VIIT N'O.- ~ort, or Other Data ' NOTICE OF INTENTION TO: TEST WATER SHUT-OFF PULL OR ALTER CASING FRACTURE TREAT j j MULTIPLE COMPI,ETE SHOOT OR ACIDIZE ABANDONS REPAIR WELL CH*NOt PLANS (Other) ~URSEQUENT REPORT OF: WATER SHUT-OFF ~ REPAIRING WELL FRACTURE TREATMENT ALTERING CASING SHOOTING OR ACIDIZINO ABANDONMEN'T~ (Other) (NOTE: Report results of multiple completion on Well Completion or Recompletion Report and Log form.) 15. DESCRIBE PROPOSED OR COMPLETED OPERATIONS (Clearly state all pertinent details, and give pertinent dates, including estimated date' of starting an}' proposed work. TBU Well D-20 had been damaged on April 28, 1975, while drilling the 17%" hole at 1480' MD. on new well D-27. The following repair work and workover resulted: (1) Moved rig 976 over well, 7/7/75, rig-up BOPE. & tested ok. (2)Cut 3%" tubing @9,749', which left the packer @9,770' and a blanking plug in the tubing @9,783 '. (3)RIH with 8%" bit & roller-reamer, located hole in 9-5/8" casing @1,497' MD. and tr~ hole with reamer. (4) Set ret. bridge plug @1,650' MD. & covered w/sand. (5) Cement squeezed hole with 650 sacks, WOC., drilled out and tested to 1,500 psi-ck. (6) Retrieved bridge plug. Ran over-shot and pulled tubing fish, packer, and blanking plug. Cleaned out fill frc~ 10,181' to 10,430' MD. (PBTD). *Marathon Oil Campany - Sub Operator 16. I hereby,d~r~"l~y that the for.~in~is true..lmd corrtct -continued- TITLE Dist, Drlg. Supt, DATE 9/26/75 (Th~4~ for State office use) APPROVED BY CONDITIONS OF APPROVAL, IF ANY: TITLE DATE See }nstrucfions On Reverse Side Sundry Notices and Reports on Wells Page TWo (7) (8) (9) (10) (11) (12) Set a penmanent packer @ 10,198' MD. with tailpipe and profile-nipple (to set blanking plug & isolate Bench 6 if water productive). Ran 41 joints of 7" OD., 29#, N-80, LT&C casing as a scab liner and set packer at 1,723' (inhibited water'in annular area) to isolate hole in 9-5/8" casing @ 1,497'. Ran 3~"2 - 4%~"2 production tubing string w/gas lift valves, circ. sleeve, ball type safety valve, and set packer @ 9,669' MD. Tested ball valve & packer - ok. Installed ~mas tree & tested - ok. Opened gas lift mandrels and tested well frcm existing upper Hemlock perforations at 3,704 BTFPD w/0.5% cut, TP-200 psi, CP-980 psi, & 3.77 MS~_WPD lift gas. Perforated Hemlock Bench 6 thru tubing w/2-1/8" scallop gun w/4 HPF under drawdown fr(xa 10,230' to 10,260'~ ~3. (30' overall). Put all benches on test together. Released rig to Well D-2A on 7/23/75 with D-20 producing 3,936 BTFPD w/0.6% cut, TP-190 psi, CP-940 psi, & 3.25 MMCFPD. Test prior to %xDrk was 2,735 BTFPD w/0.1% cut. Dear Mr. Marshall: Union Oil and Gas ~"'"sion: Western Region Union Oil Company,, California P.O. Box 6247, Anchorage, Alaska 99502 Telephone: (907) 279-7681 August 12, 1975 union Mr. Tom Marshall Division of Oil & Gas State of Alaska 3001 Porcupine Drive Anchorage, Alaska Enclosed for your files are the following reports: 99504 TBUS G-22 (12-32) TBUS G-2 TBUS D-27 (31-6) TBUS D-20 (22X-6) TBUS D-2A (13-5) TBUS K-21 (21-28) Kenai Unit #33-30 Kenai Unit #43-7 Monthly Report (Form P-4) Completion Report (Form P-7) Monthly Report (Form P-4) Formation Test #1 & #2 Monthly Report (Form P-4) Monthly Report (Form P-4) Monthly Report (Form P-4) Monthly Report (Form P-4) Monthly Report (Form P-4) Completion Report Monthly Report (Form P-4) Completion Report Completion reports for TBUS D-27 and TBUS D-20 will be forwarded' to you within the next week. Very truly yours, David A. Johnson Drilling Engineer sk Encl. cc: Marathon Oil Co. Atlantic Richfield Co. Standard Oil Co. Phillips Petroleum Amoc© Production Skelly Oil Co. Mr.. Rodney Smith-USGS F'orm REV. 8" ~- ?0 STATE OF ~J.A~S~ SUBMIT l~ DUPLICA~" OIL AND GAS CONSERVATION COAAMI~EE MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS OIL WI:LL WI:LL [~] NAME OF OP~/~ATOR OTH~lt Union Oil Company of California* ~DDR_~S$ OF 909 West Ninth Avenue, Anchorage, Alaska 99501 LOCATION OF Surface: 672.1' N, 1211.1' E from SW Corner, Sec. 6, TSN, R13W; SM At Prod. Interval: 2072' FNL, 2035' FWL, Sec. 6, TSN, R13W, SM AP1 NUMERICAL CODE 50-133-20203 'LEASE DESiGNA ~"ION AND SERIAL NO ADL ~8729 ?. IF INDIA]~. ALOTI'EE OR TRIBE NAME 8. L.~IT.FARA{ OR LEASE N.~ME Trading Bay Unit 9 WELL NO D-a0 (22X-6) '10. FIF_J~D A.ND POOL. OR WILDCAT McArthur River Field 11. SEC,. T.. R., .%I.. (BO~FOM HOI~E Sec. 6, T8N, R13W, SM 12. Pl~9-MITNO. 13. REPOSe TOTAL DEPTH AT END OF MONI%I, CHA~\'GES IN HOLE SIZE. CASING AND C~-----¥[ENTING JOBS INCLUDING DEPTH SET AJqD VOLUqVIES USED, PFA:LFORATIONS. TESTS A24-D RESULTS. FISHING JOBS. J1/NK LN HOLE A~ND SIDE-TRACKED HOLE A. ND A_NrY OTHER SIGNIFICANT CHA~G~ IN HOLE C~ONI)ITIONS. July 1975 Moved in rig 7/7/75. Cut off tubing at 9,65~' and pulled out of hole leaving the packer and tubing plug in the hole as a bridge plug above the perforations. The damaged area of the 9-5/8" casing was trimmed and rolled out with a roller reamer. The hole in the 9-5/8" casing at 1,~97' was cement squeezed with a total of 650 sacks and subsequently pressure tested to 1500 psi., OK. The tubing fish and packer were retrieved and the hole was circulated clean. A permanent packer with seating nipple was then set at 10,198' (between benches 5 and 6) in order to' isolate Bench 6, if required. A tension' packer was run on ~1 joints of 7" casing and set at 1,723' to isolate the squeezed damaged area in the 9-5/8" casing. A tapered string of 3-1/2" and h-l/2" tubing was run with a packer and gas lift mandrels and set above the Hemlock.. The well then produced from Benches 3, ~, and 5 on test at a rate of 3,70~ BFPD with O.5~ BS~J~, a tubing pressure of 200 psi and a casing pressure of 980 psi. Perforating of the remaining Hemlock section 'was completed with the addition of the Bench 6 interval 10,230-10,260'. The well then produced from the entire Hemlock section (Benches 3,h,~, and 6) at a rate of ~,1~ BPD with 1.~% BS&W, a ~OR of 350, a tubing .pressure of 160 psi and a casing pressure of 950 psi. On test completed 7/2~/75, well produced at a rate of 3,912 BOPD, 2h BWPD, and a GaR of 320. Released rig @ 7 PM 7/23/75. * Marathon Oil Company, Sub -Operator hereby ee?,~_ y tha~ the forJ~oto~_~ tr~; and e~rl~-~-~ " " " ~ . Dist. Drlg Su t NOTE--Report on this form it required for each calendar ~th~ regardless of the status of operot~ns, and must ~ filed In duplicate with oil and gal conservaf~n commlflee bythe 15~ of the succ~ding ~n~, ~ie~ otherwise directed. Union Oil and Gas DiviSion: Western Region Union Oil Company/r~ '~ Galifornia P.O. Box 6247, Ancl1,~,~ age, Alaska 99502 Telephone: (907) 279-7681 June 19, 1975 Mr. Tom Marshall Division of Oil & Gas State of Alaska 3001 Porcupine Drive Anchorage, Alaska 99503 RE: TBUS D-20 (22x-6) DOLLY VARDEN PLATFORM I sEC CONFER: FILE: . . ~. ~ .... _~__ ~.' 4,, Dear Mr. Marshall: Enclosed for your approval are three (3) copies of the Sundry Notice & Reports on Wells (Intent) for future work scheduled to be done on the above captioned well', Very truly yours, ~m R. Caltender ~ District Drlg. Supt. sk Enci. (3) cc: Marathon Oil Co. Atlantic Richfield Co. AmoCo Production Co. Phillips Petroleum Co. Standard Oil Co. Skelly Oil Co. ROdney Smith-USGS D~V:$JON OF OIL AND GAS STATE OF ALASKA ' OIL AND GAS COi)~"qERVATION COMMITTEE not use this form for proposals lo HI Ill or lo dc.t'pell or plu~, back to a dJffierent reservoir. ti.sc "AI)PLIC~,TION Fei{ PEIG%II'I.'---" for such proposals.) lo . 2. ~NA.%iE OF Union 0il Company of California 3. ADDI{]:2S$ OF OPERt%TOit 909 West Ninth Ave., ^rich., Ak. 99502 LOCATION OF WELL, ~t,~-,~ Conductor '#4 2072' FHL, 2035' Section 6, T-8-N-R-13-WSM 13. I~LEVATIONS (Show whether DF, i~T, GR, etc. DF-106 MSL FWL Ckeck Appr~rlate Box ¥o indicate Nature of N'ofice, .'Re I-~E DESIGNATION A. ND SEILIA~ ~O. . ^DL 18729 't. IF IN'DI..LN. ~'_"i'EE Ofl TRIBE 8. UNI'I'~ I"Alil~! 011; LEASE NA~IE Trading Bay Unit ii. W~-f-L NO. D-20 ('22x-6) t0. F~F. rJ).A~NrD POOL. OI~ WII~DC~T McAr.thu. r~ River .Fie-ld Hemloc 11, SEC.. T., OBJ E~-~IYE) Sec 6-T-8-N, R-15-WSM .- . 12. PEH. IVI. IT NO. ~or~, or Other Data ~'E[II' WA~ER 8I~IUT~Dr~* [ [ PULL OR ALTE~ CA~ING FRACTCBE TE~AT J J MULTIPLE COMPLETE ~ZPAIR W~L~ CHA~OB PLA~8 tother) (Norz: Report reaults of multiple completion on Well (0ther~ Completion or Recompletlon Report.~nd Log~f,or, m.} .... , "1~,. I~'aC~t~'g ,,novosz'o o~ C'O.',IPI~zo 0PZRA~OXS (Clearly state all pertinent detalia, and give pertinent dates, including estimated dat~ of starting imroposed work. · 1.. 'Well has a tubing.plug set at 9,782 feet, with packer set at 9,770 feet. 2. Rig-up wireline tools and cut off tubing about 30 feet above packer. Pull and lay down tubing. '3. Pick up drill pipe, wit.h'guaged bit and check 9-5/8" casing to approx- imately 2,000 feet. Pull drill pipe and pick up 9-5/8" packer..' Run in to approximately 1,000 feet and set packer. Cement squeeze hole in 9-5/8" Casing at about 1,450 feet with 200 sacks of neat class G cement. Wait on cement 24 hours then drill out and pressure test. Re-squeeze as required to hold 2,000 psig. 4. Run and roll Out a Halliburtoh casing patch across t'he interval 1,430 to 1,470 feet, or run. a 7" tie back liner from 9,462 to the §urface. Cement with 300 sacks' of class G as casing cond, itions require. S. Clean out to top of tubing and displace hole with diesel or polymer base, low fluid loss, low solids mud system. Pull tubing and packer. 6. Perforate Hemlock 10,230 to 10,260 measured depth. 7. Run packer, tubing, gas lift valves, sub-surface safety valve, land tubing, set packer a~d displace mud with diesel fuel. Estimate.~d Starting Date' .July 1, 1975 ~mm:D.kff~~/~. ~-~ff~-~~,,-/ ~r.~ Dist.. Drlg..Supt.. vi~ ~ 6/19/7.5 .... ....... . ..~/.' ..Ti~ R d c~)<,d:.)~?..~ .............. ~prov~ C~) ~ ~nstructlons On Reverse Side . Marathon Oil Company May 8, 1975 Mr. Hoyle H. Hamilton Chief Petroleum Engineer State of Alaska Division of Oil & Gas 3001 Porcupine Drive Anchorage, Alaska 99504 Anchor )ivision ProductiSn Operations US & Canada PO Box 2380 Anchorage Alaska 99510 Telephone 907/274 1511 Dear Hoyle: This memo is to reference our telephone conversation concerning Well D-20, Dolly Varden Platform. The D-20 well course was intercepted while drilling the surface hole for Well D-27. At approximately 1,400', a kick was experi- enced in Well D-27, and it was thought that there was possible damage to the 9-5/8" casing of Well D-20. On May 4, an attempt was made to fill the 9-5/8" casing on D-20 with diesel oil. In the process of filling the hole, we experienced diesel oil coming back to the surface of the Inlet around the Leg A-1. The pumping of diesel oil into Well D-20 was ceased.and the flow of diesel to the surface also subsided. D-20 was then shut-in and it presently has a tubing plug set at 9,783'. Marathon plans to work on Well D-20 after the completion of Well D-27, which will be in approximately 50 days. Re spect fully, H. D. Lee Acting Operations Superintendent HDL/sg xc: C. F. Ferguson D. L. Jones I .AY 1975 BIVISION OF OiL Form P--3 (- I~_~V. 9-30-6 9 STATE OF ALASKA ~abmit "Intentions" in Triplicate I %' & "Subsequent l~eports" in Duplicmte OIL AND GAS CONSERVATION COMMITTEE SUNDRY NOTICES AND REPORTS ON.. WELLS (Do not use this form for proposals to drill or to deepen Us~ "APP-LiCATION"FOf~'/~-~'1~--~' 'for such 1, oI,. [] oas WELL WELL OTHER 2, NAME OF OPERATOR Marathon Oil Company . 3, ADDRESS OF OPERATOR P. O. Box 2380, Anchorage, Alaska 4. LOCATION OF WELL 99510 At surface Conductor #4, 2,072' FNL, 2,035' FWL, Sec. 6, TSN, K13W, SM 13. ELEVATIONS (Show whether DF, RT, GR, etc. DF 106~ MSL 14. Ch~d( Appretariate Box To [ndkate Nature of I~ti'c'e, Re AP1 NU'ME, B/CAL CODE i6. L.EA, SI~, DESIGNATION A.ND SERIAL NO. ADL 18729 9. IF LITDIAN, AJ.J~OTTEE OR TRIBE 8. UNIT, FAB.M OR LEASE NA1ViE Trading Bay Unit 9. WELL NO. D-Z0 (22X-6) 10, F~,r) ~ FOOL, OR WILDCAT McArthur River - Hemlock 11. SEC., ¥'., ail' M., (BOTTOM HOLE OBJECTIVE) Sec. 6, T8N, R13W, SM 12. PEI~ViIT 1~O. zort, or Other Da~a ' NOTICE OF INTENTION TO: TEST WATER SHUT-0FF I t PULL OR ALTER CASING J~J FRACTURE TREAT j j MULTIPLE COMPI,ETE SHOOT OR ACIDIZE ~ ABANDONs REPAIR WELL CHANOE PLA~S (Other) 8UBSBQUENT REPORT OF: FRACTURE TREATMENT ALTERING CASING SHOOTING ~ ABANDONMENTS (Other) NoTE: Report results of multiple completion on Well om,pletion, or Recompletion Report and Log form.) 15. DESCRIBE PROPOSED OR COMPLETED OPERATIONS (Clearly state all pertinent details~ and give pertinent dates, including estimated date of starting an}' proposed work, 1. Rigged up Otis wireline unit, hydrotested lubricator, and pulled ball valve on October 1Z, 1972. 2. Rigged up Go-International and hydrotested lub.ricator. 3. Reperforated thru tubing with well lifting: 40 holes from 230 " " 150 " " 4. Rigged down Go-International. 5. Rigged up Otis wireline unit and installed ball valve. 6. Returned well to production October 13, 1972. 9,850' to 9,830' 10,065' to 9,950' 10, 175' to 10,100' NOV 2 OlVI$1C, N CF OIL AND GAS ANCHORAGE lB. I hereby certify that the foregoing, ti tr~e and correct ~,TL,~Div. Drilling SuperintenderiDATE ,, //-~-/- 7,,0- (This space for State office use) APPROVED BY CONDITIONS OF APPROVAL, IF ANY: TIT~E DATE See instructions On Reverse Side 10orm No. P---4 REV. 9-~-67 STATE OF ALASKA OIL AND GAS CONSERVATION COMMI'Fi'EE SUBMIT IN DUPLICATE HLB ~ i i%i'vt -'- · _ 50-133-20203 ADL 18729 R~L ~ MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS 1. WELL wELL OTHER 2. NAME OF OPEP,.ATOR Union 0il Company of California* 3. ADDRESS OF OPEP~TOR 2805 Denali Street, Anchorage, Alaska 99503 4. LOCATION OF WELL Surface: 672.1' N, 1211.1' E from SW Corner Sec. 6-TSN-R13W-SM Prop. Prod. Zone: 1980' S, 2940' W from NE Corner Sec. 6-T8N-R13W-SM 7. IF INDIA]~, ALOTTEE OR TRIBLt~q'A-M~- I ~ Trading Bay Unit g. WELL NO. D-20 (22X-6) 10. F~ A_ND POOL. OR WILDCAT McArthur River Field 11. SEC., T., R., M., (BO'I"TOM HOI.,E Sec. 6-T8N-R13W-SM 12. PERMIT NO. 69-95 13. REPORT TOTAL DIEP~Ti-I AT END OF MONT~I, CH. ANGF. S IN HOLE SIZE, CASING A_N'D CEIvlENTING JOBS INCLUDING DEPTH SET AINrD VOLI3/~ES USED, PE_R~O'I:L~TIONS, TESTS A_N-D RESULTS, FISHING JOB~, JLrNK IAI HOLE A_ND SIDE-TIR3~CKED HOLE A2q'D ANY OTHER SIGNIFICANT CX-)Jk~TG~ IN HOL~ CONDITIONS. Trading Bay Unit. D-..20, Novembert' )969 11/1 - 11/2 Drilled retainer at 9515'; perforated 4 holes per foot from 9680 to 9681'; set retainer at 9508'; squeezed perfs with 150 sacks cement at 5600 psig. 11/3 - Ran cement bond log which indicated approximately 80% bonding from 9663 to 9669', from 9677 to 9680', and from 9744 to 9749'; set packer at 9379 for drill stem test; opened tool for 60 minute flow period; medium blow for 6 minutes, slight blow for 45 minutes, shut in for 31 minutes; recovered 106' of drilling mud and water in excess of water cushion; IFP 911 psig, FFP gl1 psig; FSIB 1350 psig. 11/4- 11/5 Conditioned hole for perforating; perforated Hemlock from 9820-9885', 9910-10,065' and l0 090-10 190' , , , ; conditioned hole to run tubing. ll/6 - Ran 4-1/2" and 3-l/2" tubing; packer set at 9770'; tested Packer to 2000 psi; rig released at 9:00 p.m. 11-6-69. * Marathon 0il Company, Suboperator, Dolly Varden Platform 14. I hereby certify that the foregoirl~is lr~ and co~e~ ' NOTE~Report on this (or~ requ{red for each calendar month, r egacdless o( the status o( opeFat{on% and must ~ (i{eU {n duplicate with the Division of ~ines & ~}nera{s by the lSth of the succeeding month, unless other}se directed. Form P 7 < SUBMIT IN DUPLI STATE OF ALASKA ',See other ~" C~ t.~ t~ structions on OIL AND GAS CONSERVATION C.~! ./V~TT~E ,eve¥s~ sid~ 5. ~z ~~ ~D~ ..... : ::: 50-133-20203 ~ m mmm m m ~ELL (O~PLET)O~ OR RE(O~PLET)O~ R~O~T~A~D LOO ~ b. TYPE OF COMPLE~ON: ./~~' WELL OVER EN BACK RESVR. '~ C~, ~ 2. ,,.. o, o,.,,.o. *~ ~ '- Trading Bay Unit- Union 0il C~pany of California* .;~ > '9. w~,o. · ~ ~ ..... 2805 Denali Street, Anchorage, Alaska 995~ ,.-- -.: ~... ,o.,.~ ,,, (9 67 · ~ ~, i'*~'"a~' 2.]' N' ]2ll.]' E from S~ Cotnev~C~L~-TSN-RI3~-SH . - ~ o~v~) It to) ~rod. interval re~orted below 2072'FNL, 2035' ~d~6-TSN-R13W-SM ~,- ~ r ~. ~sec. 6-T8N-R13W-SM ,, tot,~,~pm 1884' FNL, 2163' ~L, Sec..6-TBN~I~S~ ....... l~. P~Z~ ~o. - c.~ 69 95 9-19-69 [ 10-27-69 [ 11-6-69 ,. -.:,..F~ DF 106 ' ~' I CABLE TOOLS 10,OZI'TVD "/ 9,955' TVO ,, / ~°w~*~ ~' t ~o~,~ ~o~ ln_~n~, Mn / In aqn, MD~ I' ' "~=- I u- lU~50'6'. [ ~. PRbb0~IN~ m'IJ~VALCS), O~'~g ~M~TIO~o~, 'BOSOM, N~E~ ~D ~)* ' 123. W~S DIREC~O,N~L .., . . Top 9,804 .MD, 9,363 TVD ~ ~ uemlocK' ~ ,: , ~ ~ ~ ~ ~; ~ ' Btm: 10,276 ~MD, 9,808 TVD - ~' ) Yes DIL, Density,. Sonic, Cement"Bond ~:~.~- = · ' ' ' ;, - : ......... ~, . c' ~u) :l' ":: , ~' <': '~ CiS~ RE~ (Re~t all .,strmg~t ~ / CA~G SiZE 'l- WEIG~ 'LB/FT. I:"~ G~E?'i DEPE SET. (~) i ~ ~E .I C=I:~NG =CO~ ' aO:T PULL~ ;' -5/5 .:. [40,43.5,47~N80,.:..[ 9674' st: :0o sac s. · i- l 2nd: 1200 sacks: iii 26. LINER ~CO~ , ~.:) !27. 7" t 794~',' I loJ4so'[ S00 I:~:.- "" 4-~/2" [ .. ~n, . [ t : ,[ " Lc c 3-1/2" t ' ~))b' 9770' 28. PERORATIONS OP~ TO ~O~U~'~O~~ ([nte~al size and numbe~) 29 ACID, SHOT, F~CTURE, C'~NT 9,880 -. ,885' 1 9,910- 10,065' a: -- .... ::...[ :-: ' i;:~ :: · 10,090' 10,190' ~ <:" ~" ANCHO~tG~ . DATE FIRST P~ODUC~ON '[ ~ODUCTION METHO'D (~owh~.g, gas liit, pumping--size and t~e Of p~p) 11-8-69 '- '[ .Gas Lift ' . : .~ .... [ Producing DAT~ 0F T~ST, [EONS ~ES~ I~toxE SIZE I~OD'N FOR OI~BBL. "~~CF. WATE~B.~ [ GAS-Om ~TIO " ! :< I' lEST v~o~ j, -,- , I ~ l - 16-69 ! .24 ," i, o~en,, I ~'-, [:~ 3596 I 488 [ "] 4' .1 136 . I - l'~ [ 3596' $ <~488<'::'- I 14 I 33.2, 31. DISPOSITION OF GAS (2old, used for fuel, vented~ etc.) . ' ~ 0% ~ ~-~ ITEST WITNESSED BY Fuel and vented ~ ...... '.2 ] E. F. ~cFarland 32. LIST OF ATTACHMENTS ~3. i hereby certify that the foregoing and ~ttached in~rmation Is complete and corre~'t as determined from alFavailable records SIGNED ' TITLE i ., ~lg~: Supt. DATE 12/12/69 · (See [.s~r.cfio., ~.~ Spoces [o, Addmo.c[ Dna o. Rever~e Side) · Marathon 0ii Company, Suboperator, Doily Varden P]atfom OKG _~. K LV ..... ADL 18729 REL ./_~ ,: Z~l/ 7. IF INDIA.N, A.I_J.~TTEE OR TI:~BE NA.M~ -------- ~ INSTRUCTIONS ::.;: Geq.ejra l: This form is designed.~.f.0.L' submitting-a complete and correct, well compl,.eti.,On report a~,.c{. Iog.,./?n ,, .... '~.z. all tYpes of lands and leases--i~n .A_Ja. Ska... ": · ,: '" :' ' ' ..... " . '; C ........ ' . · ~-Item:' 16: Indicate which el:eVati6~' is us'ed as~referenCe".(where not otherwise s~Pwn)-'for depth., measure- , ~ .. ~ZmenJfs given in cther spaces on ~tbis form'and i~0 any attachments. .. :~iilte~ 20~.~n~ :22:: If this well is comply, ted foj~ separa, tp.prod'uction from more th~in i.'one interval zone :.:._:(mu'DiPe"comp eti'on), so s~'~'~e in item 20, an~{ in iterf~"22 show the. prcducing i'nterval, or intervals, ..: top(¼'), bottom(s) and name (}) (if any) for.. onl~)."the inte~'wS{ reported in.,item 30. Submi! a separate report (page) on-..this fOrm, adequately identifie~l, fol.. each addit'ional inte~va'l to be seperately produced, show- -~-ing ihe ~Oditional. data pertine}qt 'to sbch interval. - ~.lt.m26: ~:.,~acks Cement": Attached s~pplem~ntal records" for this welhshould show the details of'any mul- ,'-tiple:' stage cOknenf'ing and the Ioc~atidn' ~'f the'.cement[n'g to011' '~Jtem' 28: :~ubmit a separate~'completioO, 'repor. t on this 'form 'for each-'interval to be separately p~oduc~t. :(See instr~cti~Sn fC~'~' items 20 and 22 'abOve).. --,,~ .., ;.~ .' .... ~,. -. ~'?5~[~'ARY OF' I~)~MATION .TEST$'.INC~UDIr,/~] INTEP~VAD T~ED, p~U~ DATA ~ ~OV~"OF OIL, ~,~ ..... " 35. " : ': WAT~ AND MUD sgem tested ~h pa~cker ~g'eg ag 9379'; opened goal fO~"60 minute flo~ ,,, med~um blo~ for ~;m~n0.~es, s]~ht b]o~ for 45minu.tes, shut ~n for g~S .j 4,670' 4,483' ~r~utes; recovered 106:' '~.dri'll ~n~ mud and ~ater in exces~ :6f IFP 911 p's~, FFPgll~'ps~; FSIP 1350 ps~. · Hemlock 9,804' . ~. ' ,:.. ,.~ ~est Foreland 10,276' 9,808' ; ~' ~_. :~.. '~ .... · .. , .. :.? ~'~ . ~. ~ .., .' . ., ~ ...... . ,,., , , .. , DATA, A~ACI[...BRIEF D~CRIP[~ONS OF LITHOLO~Y POROSITY. F~AC~R~, AP~NT DIPS. ~.- .....: .. . , ~'~ , ",~:':AND~_ D~iPECTgl).~IOWS O~ OI.L, GAS OR WA~. t ,, i;' '5" ~"~ : , , '~ ' .... ~ ~,~ - Z'. ' ~ -: ,' i ' . ,? · i , .... . . .. );%TE~ -,i 2/3/69 M/~^~TH{3N OIL CO~fiP~Y HIS'[ORY OF OIL OR GAS W r~LL WELL NO. D-20 STATE Alaska LEASE Trading Bay Unit -Dolly Varden ~~ P lIa t f om COUNTYKenai Peninsula Borough M E/~$UR Eh1 ENTS TAKEN FROM ELEV. rTop OF OIL STRING ELEV ITOP OF ROTARY TAmaLE lZ'LEV ~GRD. OR IV~AT ELEV. 106 MSL SEC. 6 ,TWP. 8N R...13W 2066 FNL & 2907 FWL, Sec. 6, T8N R13W SM HISTORY PREPARED BY. W. E. Rourke TITi.]E. ..... Adv. Petroleum Engineer · It is of the greatest impo~'Jb~c'e to hove a complete history of the well. Use this form in reporting the history of all important operations ' et the well, together with the dates thereof, including size of hole, size and number of bits, complete description of casing, cementing, fishing or drilling difficuhles, surveys, oil tests, oil completion operations and procedure, etc. DATE -18-69 -19 -2O -21 -22 -23 9-24 9/25 9/26 Santa Fe Drilling Company Rig ¢)76 TD 400' - Rig released from D-18 at 1300 on 9-18-69. Skidded rig over Slot 4. Cleaned out conductor with 17~'! bit to 400'. TD 817' (417') - Drilled 17~" hole from 400' to 789'. Ran turbo-drill ~)1.. Oriented tool N-18°-W.- Drilled 28'. Cones locked. Spudded well at 12:30 PM (9-19-69). TD 1677' (860') - Ran turbo-drill f~2 & oriented due north. Turbo-drilled 'from 9,50' to 1094'. Pulled turbo-drill and ran in hole with drilling 'assembly. Drilled & surveyed to 1677'. TD 3000' (1323') - Drilled & surveyed 123~" hole from 1677' to 1771'. Pulled out of hole. Picked up and ran 'turbo-drill ~3. 'Oriented tool & turbo-drilled to 1836'. Tripped to pick up drilling assembly. Drilled & surveyed 12~" hole to .3000'. · TD 3050' (50') - Drilled 12~" hole to 3050'. Pulled Out of hole & picked up 17~" hole opener. Ran back in & opened 12~" hole to 17~" from 789' to 2350'. TD 3050' -- Completed opening 12~" hole to 1~'" fr~m 2350'-to 3016' at 5:00 PM 9~23-69. Strapped pipe out of hole. OK. No' correction: Ran back in hole & circulated & conditioned mud .to run 13-3/8" casing. Rigged up & ran 78 jts. 13'3/8"~ , 6I~, K-55, Rge-3, Cond-1 Seal lock casing with Baker differential fill shoe & collar. '(2962.39' net) Landed shoe at 3006.19' K.B. Rigged up & Began circulgting- , - 13-3/8" Casing. Detail Effective Length 76 jts - 13-3/8" 61f~ Kz55 Rge-3, Cond-1 Seal lock Casing 2883.49' · ~ :~ ' 1~ 13-3/8" Baker Differential Fill Collar . 1.90' 2 jts - 13-3/8", 61f~, K-55, Rge-3, Cond-1 Seal Lock Casing 74.50' 1- 13-3/8'~ 'Baker Differential Fill Shoe 2.50' Total Net String..., ......... ~ ......... 2962.39' .. Ran ~- 13-3/8" Baker centralizers at following depths: 300' 2964' 2929' 2888' 2852' and 2812'. TD 3050' - cemented 13-3/8" Casing' with 2000 sacks Class "G" cement with 4% gel and ½ cu. ft. perlite/sack. Tailed in with 400 sacks Class "G" Neat cement with '2% CaC1, 13.5~ Slurry, used 15% excesJ cement volume. PumpeH 40 bbls. water ahead of cement slurry & 5 bbls. water behind slurry. Displaced with 451 bbls. of mud with rig pump. Bumped plug with 2000 psig, held ok. Plug down at 12:15 PM. Good Returns while cementing. Got 50 sacks to surface. W.O.C. 12 hrs. & landed casing. Released rig at 3:00 AM - 9/25/69 to move to D-4. Static - Waiting on rig. TD 3050' - Moved rig from DA4 to D-20 at 3:00 PM 9-26-69. Nippled up & tested casing with 1000 psig for 15 min. Ok. Tested BOP's with 3000 ps~g for 15 min. OK. / / ELL NO. TATE · ~ E~S U R EM ENTS TAKEN FROM D-20 Alaska ..... ,,~ uF OIL OR GAS W'ELL . . LEASE Tr~ng Bay Unit - Dolly Varden ~. 6 8N SEC .TWP, r. Kenai Peninsula Borough COUNTY. EL. EV. W. g. Rourke -- [LEV._ H. 15TORY PREPARED bY __ ELEV_ TITIiE. "TOP OF Oil STRING TOP OF ROTARY TABLE Adv. Petroleum Engineer GRD. OR MAT_ E L r V. _]..0_6__MSL It is of the greatest impo'~'(b:n~e to have a comp[eta history of the well. Use this form in reporting lhe history of all impodanl operations at the well, togelher with the dates thereof, including size of hole, size and number of bits, complete description of casing, cementing, fishing or drilling difficuities, surveys, all ~ests, all completion operations and procedure, eta. DATE )~/27 )/28 9/29 9-30 lO/l. 10/2 {lO/3 '1o/4 10/5 · lO/6 10/7 10/8 10/9 lO/lO 10/1l 10/12 %o/13 10/14 ~.o/15 TD 3904' (854') - Drilled float collar and shoe. Drilled and surveyed 12~" hole from 3050' to 3904'. Tripping for new bit.· TD 4900' (996') - Drilled and surveyed 12k" hole from 3904' to 4900'. Tripped for new bit at 4596'. .. · . · TD 5486' (586') - Drilled & Surveyed 12t" hole from 4900' to ·4993'. Tripped for new bit. Drilled to 5310'. Tripped to change drilling assembly ..... . TD 6161' (675') - Drilled & Surveyed 12t" hole -from 5486 ' to 6~61 '. Tripped for bit changd .at .6005 '. ._ . TD 6535'. (374') - Drilled & Surveyed 12t" hole from 6161' to 6317'. Made trip for new bit. Now drilling at 6535'. TD 7006' (471') -' Drilled & Surveyed 12t" hole from 6535' to 6704'. Tripped for bit change. Drilled to 7006'. TD 7216' (210') -'Ran in well with Turbo-drill #3. 'Oriented turbo to'left. Drilled from 7006' to 7030'. Came out of hole. Ran in hole with drilling assembly & drilled ahead to 7216'. ' · · TD 7513' (297') ~ Drilled & Surveyed 12~" hole from 7216-' 16 7355". Tripped for new bit. Drilled t~ 7513'. · TD 7824' (311') - Drilled 'from 7513' to 7824'. Tripped for new bit at 7558'. · . ,. TD 8069' (245') - Drilled & Surveyed 12t" hole from 7824 to. 8069'. ·Tripped for .new bit at 7868'. · TD 8416' (347") - Drilled & Surveyed 12~'' hole from 8069 to 8416". ·Tripped for new bit at 8088'. Cleaned out fill from 8053' to 8088'. TD 8567' (151') - Drilled 12~" hole t° 8418'. Tripped for bit change. Drilled & Surveyed to 8567'. Pulled out of hole and picked up turbo drill #5 wi~h 2~o kick sub. TD 8691, (124') - Went in hole with turbo-drill #5 & Drilled from 8567' to 8584'. Pulled out of hole. Layed .down turbo-drill and pi. eked up drilling assembly. Drilled & surveyed 12~" hole from 8584' to 8691'. Tripped to 'change drilling as s emb ly. TD 8876' (185') - Dri'lled to 8755' · Tripped for new bit. D~lled to 8876'. TD 9095' (219') - Drilled & Surveyed 12~" hole from 8876' to 9095'. Tripped for bit change at 8886'. TD 9310' (215') - Drilled & Surveyed from 9095' to 9310~. Tripped for bit change at 9131'. TD 9418' (108') - Ran S~erry-Sun Gyro on 13-3/8" casing to 3006'. Drilled & Surveyed from 9310' to 9418'. Tripped for bit changes at 9310' & 9418'. \ TD 9502' (84') - Drilled & Surveyed 12%" hole from 9418' to 9502'. Pulled out of hole to change bit. TD 9678', (176') Drilled & Surveyed from 9302' to 9678'. with trip for bit change ut 9658'. 'ATE: PAGE 3 M/r'~,ATHDA! OIL CEliVlP"~iMY HIS,DRY OF OIL OR GAS ¥~,.':LL D-20 'LEASE Trading Bay Unit-Dolly Varden 6 /ELL NO. ......glatform SEC. ;TATE Alaska COUNTY. Kenai Peninsula Borough FIELD 8N '13W ,TWP. R. MEASUREMENTS TAKEN FROM ELEV. , fToP OF OIL STRING ELE~/._ . IToP OF I~OTARY TABLE__'ELEV. I, GRD. OR MAT L. ELEV. 106 MSL W. E. Rourke H, ISTORY PREPARED BY TITLE Adv. Petroleum Engineer It is of the greatest importonce to hove a complete history of the well. Use this form in reporting the history of oil impodant operol;ons at the well, together wilh the dates thereof, including size of hole, size and number of bits, complete description of casing, cementing, fishing or drilling difficuh;es, surveys, all tests, all completion operations and procedure, elc. DATE io/i io/i7 i0/i8- TD 9748' (70') - Drilled to 9748'. Made wiper trip & conditioned h01e & mud. Rigged up Schlumberger & ran D.I.L. from 9730' to 3008'.. Now running formation density log. TD 9748' (0!) - Ran Formation Density log from 3009' to 9732'. Rigged down Schlumberger. Made trip & conditioned mud & hole. Changed BOE rams to 9-5/8", and' began running 9-5/8" casing. 105 jts. 23 jts, 1 it. 19 jts. 24 its. 48 j ts. 12 jts. 2 jts. 1 233 its 915/8" CASING DETAIL -9-5/8" 47#, Rge-3, AR-95, S.L. Csg.' 9.-5/8" Baker Self fill differential shoe, Effective ,Length 9~5/8'', 40#; Rge-3,N-80', Buttress Csg. 4348.38 feet. 9-5/8" 43.5#, Rge-3,N-80, Buttress Csg. 1055.04 feet. 9!5/8" Baker D-V stage collar 1.81 feet. 9-5/8" 43.5#, Rge-3,N-80, Buttress Csg. 709.05 feet. 9-5/8" 47#, Rge-3,N-80, Buttress Csg. .92~.03 feet. 9-5/8" 47#, 'Rge-3, S-95, Buttress Csg. 2/SLX Butt x-over 1992.41 feet. 9-5/8" 47#,Rge-3,AR~95 Seal lock Csg. 510.48 feet. '9-5/8" Baker Self fill differential Collar 1.75 feet - 86.96 feet 2.50 feet · Spotted centYalizer,s at 'following depths: ' Total Overall 9632..41 feet · · 9660 9540 9499 - 9414 93.71 9200 9157 158 118 76 ' ,. · Completed running 233 jts 9-5/8" casing as above. Landed shoe at 9674'; top of float collar'at 9583 and top of D-V s~age collar at 5204'. Cemented casing in two stages as follows: 1st Stage: 1000 sks "G" cement w/47o gel, 200 sks ,G" cement w/6% gel, all having 1/2 cu ft/sk, of perlites, 0,5% R-5 & 1% D-!9. 500 sks class "G" neat cement w/0.5~ R-5,. 1% D-19. Pumped 10 bbls. mud Sweep ahead of slurry. Displaced w/714 bbls mud with rig pump° Bumped plug w/1550 psig. Plug down at 6:10 PM. 2nd Stage: 800 sks "G" Cement 2/67° gel & 1/2 cu ft/sk of perlites & 400 sks of neat cement. Pumped 10 bbls mud sweep ahead of slurry. Displaced w/393 bbls. mud with rig pump.' Bumped plug w/2600 psig. Plug down at 12:10 AM. All plugs held. Slurry weights - 13.5# & 15.4#. .. Circulated 3 hrs. between stages. Had good .returns during both stages. Got 80 bbls. cement back on second stage. Landed casing in slips & cut off. Nippled'down BOE & released rig at 6:00 AM 10-19-69 to move to D-10. ; TD 9748' - Released rig' from D-6 to D-20 at 10:00 PM (10-21-69). Nippled up BOPS and pressure tested casing and seal assembly with 2500 psig for 30 min. Casing OK. Ran 150 sacks cement "top job" on 13-3/8"x 33" annulus. Cemented to surface. ~ )ATE PAGE 4. ~:,~IV]~ATH O N OIL HIS~'ORY OP' OIL. OR GAS W£LL FIELD: YELL NO. D-20 3TATE Alaska LEASE Trading Bay Unit-Dolly Varden SEC. 6 MX~4~x~ Pi atIf0~ COUNTY Kenai Peninsula Borough 8N TWP. ELEV. ToP OF OIL STRING .. _ ELEV. MEASUREMENTS TOP OF ROTARY TABLE ELEV .... TAKEN FROM [GRD. OR MAT [C'LEV._ 106 MSL H. ISTORY PREPARED E~Y TITLE W. E. Rourke Adv. Petroleum Engineer It is of the greatest importance to have a complele history of the well· Use this form in reporting the history of all important operations at the well, together wilh the dotes thereof, including size of hole, size and number of bits, complele description of casing, cementing, fishing or drilling difficulties, surveys, all tests, oll completion operations and procedure, etc, DATE :)/22 0-23 .0/24 _o/25 i0/26 i0/27 io/28 TD 9788' (40') - Finished nippling up. Changed "0" ring in hydril. Tested riser & BOPs to 3500 psig. Tested 9-5/8" casing to 2500 psig. All tests ok. Installed rubbers on drill pipe. Drilled dut. D-V collar at 5206". Tested collar w/2500 psig. OK'~. Drilled.outflo~collar at 9§82'. Tested casing to 2500 psig. OK. Drilled out shoe-and hard cement to 9676'. Drilled new hole to 9788'. TD 9875' (87') - Made trip at 9788'. Ran back to bottom & started displacing fresh water mud with invert emulsion mud. Plugged bit. Pulled out.of hole, replaced bit. Ran bac~ in hole & drilled to 9875'. · TD 10,212' (337') - Drilled &.Surveyed 8%" hole from 9875' to 10,212". Pulled out of hole to change bit. TD 10,506' (294') - Drilled & Surveyed 8%" hole from 10,212' to a total dept~ of 10,506'. Started circulating to condition hole & mud to log. TD 10506' - Conditioned hole & mud for 2 hours. Pulled out of hole. Had tight spot at 9728'. Rigged up Schlumberger & ran in D.I L. log to 9830'. Tool stopped Ran back in h:ole with bit. Cleaned out bridge at 9830.- Cleaned out bridge & fill from 10,481 to T.D. Circulated two hours. Made wi-per trip & had tight hole at 9713. Pulled up into casing at 9674. 'Waited 30 min. Ran back to bottom. Hit bridge at 9839'. Stuck pipe. Jarred pipe loose & .pulled up into casing. Had tight hole 'at 9745'. Started to weight up mud. TD 10,506'. Cleaned out bridges at 9745, 9838, 9919 &.42' of fill. Circulated 2% hours. Made short trip. Had tight hole. 'at 10,440',10,380' and 10.,010'. Cleaned out 3' of fill. Came out of hole to run logs. Ran Schlumberger logs as followst DIL-9660 to 10,481' FDC-9660 to 10,480' & BCS-9460-10,477' Drillers T.D 10,5'06 S-J T.D. 10,481[ Ran in hole with bit &. conditioned Hole & Mud for 2~ hrs. Schlumberger tops: . Hemlock 9804 (9364' TVD) West Foreland 10,276 (9781 TVD) . .- TD 10,50 6 ' 7" Liner Detail Ran casing as follows:' 5" Drill pipe 9468.50 fee~ 1 Brown 7" S.S. Packer 9.19 feet 1 Brown 7" M.C. Limr Hanger 9.33 feet 22 its. 7" 29# N-80 Rge-3 X-line Csg. 946.13 fe~t 1 Brown x-over x-line - 8 R.D. .85 feet 1 Brown landing collar .89 feet 1 jr. 7" 29# N-80 Rge-3 x-line Csg. 43.08 feet 1 Brown float shoe 2.03 feet To~l Overall 10,480.00 feet Spotted Centralizers (10) at following dePths: 10,465' 10,365' 10,270' 9,650' 9,607' 9,627' 10,246' 10,190' 10,110' 9,593' 9,564' 9,541' 10,020' 9,932' 9. ,850& 9,488' 9,826' · '\ 3ATE,~--. - YELL NO. D-20 STATE Alaska PAGE 5 ~q~ATHON O~L CO~IP~,NY HI~,'ORY OF OIL OR GAS FIELD LEASE Trading Bay Unit-Dolly Varden SEC.L 6 TWP. F~~ Pi at form COUNTY Kenai Peninsula Borough 8N R.. ., ELEV. [ToP OF OIL STRING __ M E/~SUREM ENTS / tToP OF ROTARY TABLE, TAKEN FROM / ELEV,. ELEV.. ELEV, 106 MSL W. g. Rourke H~ISTORY PREPARED bY. TITLE, Adv. Petroleum Engineer.. It is of the greatest importance to have a complete history of the well. Use this form in reporting the history of ell important operations at the well, together with the dotes thereof, including size of hole, size and number of bits, complete description of casing, cementing, fishing or drilling difi'icuhies, surveys, all tests, all completion operations and procedure, etc. DATE ~.0/28 :ont 'd 10-29 lO/3O fo/31 11/1 11/2 11/3 1I/4 · . 7" 29# N-80 Rge-3 x-line casing Rigged up to run 7" iirmr Ran 23 its , , , , , with Brown M C Hanger, SS Packer, shoe & collar (1011.5' net). Shoe landed at 10,480', with collar at 10,434'. Top of hanger at 9462,50'. Ran 10 centralizers & 8 turbo ~ amps on liner. Pumped 300 sacks of Class "G" Cement w~h 0.5% R-5 & 1% D-19. Displaced cement with 153 bbls. mud. Underdisplaced cement 50 barrels. Did not bump plug. Pulled off liner. Reversed out 100.sks. cement· Job 'completed at 5:00 ~. Went in hole with bit and tagged top of liner at 9466'. Top of cement in liner, at 9592'. Estimated top of cement in -annulus at 9847'. ~ · PBTD 10,430' - Drilled &-cleaned out cement to 10,430. Circulated~ hole clean. Ran Schlumberger cement bondl0g in well. Logging tool failed. Ran in well with 7" casing scraper. Ran scraper to 10,430'. Circulated hole clean. Pulled out of hole to run cement bond log. .. PBTD 10,430' - Ran Schlumberger Cement Bond log from 10,430' to 9,450'' Had good bond.from 10,400' to 9,960'. Top of cement in annulus estimated at 9,960'. -Ran bond log from 8,450' to 9,450' and 3,500 to 2,000'. Had good b~nding in 13-3/8" annulus from 2,000' to 3,500' & good bond{ng from 8,450' to 9,450'. Schlumberger perforated 7" liner with 4 (1/.2") holes at 9750-9751". Attempted to run EZ drill cement retainer on wireline. Could not'get in top of lirar. Ran 6" x 7-3/4 pilot mill. Milled-out top of liner to 6". Pulled. ~ut of hole. PBTD 10,430' -'Ran in, hole'& set 7" HoWco EZ drill retainer on wireline at 9500', Ran Drill pipe and stung into retaine~. Squeezed perforations at 9750-51' with 75 sacks cement, preceeded by 10 barrels of diesel & 10 barrels of water. Cement in place at 4:45 PM 10-31-690 Pulled out of hole to drill oUt retainer. · · PBTD 10,430' - Went in ~ole with 6" bit & drilled retainer at 9515'. Ran bit to 9700' & circulated. Pulled out of hole. Rigged up & perforated 4 (1/2") holes at 9680-81'. Ran 9-5/8'.' gauge ring to top of liner. Ran 7"-gauge ring, but would not go in top of liner. Ran bit & scraper .to 9700'. · , , PBTD 10,430' - Ran .HOWCO 7" EZ drill cement retainer & set at 9508'. Pressured annulus 'to 2000 psig. Broke d~n perforations 9680' - 9681' with 4800 psig. Pumped into perforations at 1~ BPM rate. Squeezed perforations with 150 sacks, type "G" cement with 0.5% R-5 at 5600 psig. lO0 sacks out perforations. Reversed out approximately 5 barrels of cement. Pulled out of hole. ~icked up bit & two d~ll collars, & ran back in. Circulated & conditioned mud at 9400~. Drilled retainer at 9508' & hard dement to 9683'. 'Open pipe to 9730'. Drilled cement from 9730 to 9755'. PBTD 10,430' - Ran in hole with bit.'& conditioned mud. Pulled out of hole & rigged up Schlumberger. Ran cement bond log wbich indicated approximately 80% bonding from 9663' to 9669' , from 9677 to 9680' & fr~n 9744' to 9749'. Rigged down Schlumberger. Picked up & ran HOWCO DST tools. Set packer at 9379'. Opened tool for 60 min. flow period. Medium blow for 6 min., slight blow for 45 min. Shut in tool for 31 min. Pulled test tools out of hole. Recovered 106' of drilling mud & water in excess of water cushion. IFP 911 psig, FFP 911 psig & FSIP 1350 Psig. PBTD 10,430' - Finished laying domn DST tools. Ran in hole with 6" bit and ~" casing scraper to'PBTD. Circulated hole clean. Pulled out of hole and rijged up Schlumberger. Perforated Hemlock from 9820-9885, 9910-10,065 and 10090-10190'. (dil meas). Rigged down Schlumberger. Laid down drill pipe. ATE,- .12/3/69 PAGE 6 MP"'~ATHI:::)N OIL COMP"~NY HIS I'ORY OF OIL OR GAS WELL 'ELL NO. TATE MEaSUREmENTS TAKEN FROM D-20 Alaska LEASE Trading Bay Unit-Dolly Varden SEC., 6 F~%~J~K Pi at form COUNTY, Kenai Peninsula Borough ELEV. 'ToP OF OiL STRING __ ELEV H. ISTORY PREPARED ~3Y. TOP OF ROTARY TABLE. ELEV._ TITL:E C~RD, OR IV~AT ELEV. 106 MSL FIELD 8N 13W ' ..TWP. R. W. E. Rourke Adv. Petroleum Engineer It is of the greatest impo]:~6~c'e to have a complete history of the well. Use Ibis form in reporting the history of all important operations ' at the well, together with the dotes thereof, including size of ho~e, size and number of bits, complete description of casing, cementing, fishin9 or drilling difficuities, surveys, all tests, all completion operations and procedure, elc. DATE: ~.1/5 11/6 PBTD 10,430' - Finished laying down drill pipe. Picked up tubing. PBTD 10,430' - Finished going in hole w/285 jts. 4~" tbg. ,'12 jts. 3½" tbg., gas 'lift valves and packer. Packer set at 9770' with'tailpipe at 9785~. Ran 4~" ball valve in place. Removed BOPs, installed-xmas tree and tested to 2500 psi - OK. Displaced mud w/diesel, dropped ball and set packer. Tested packer to 2000 psi - OK. Rig released at 9:00 I~_~ 11-6-69. SYMBOL OF SERVICE REPORT of SUB-SURFACE DIRECTIONAL SURVEY MARATHON OIL COMPANY COMPANY TRADING BAY UNIT D- 20 WELL NAME COOK INLET, ALASKA JOB NUMB~ AM9-2969 TYPE OF SURVEY SINGLE SHOT DATE SEPT - OCT 1969 anchorage -_ .... _-.~'.-_-'_--__-.-.~-_'_-_~ii~_'_-~-_~':'~i~-T~-~-Tc~E~~!Y !~_~20 WELL_ C,U"PLETION RPT PREPA,Eg BY SCS 1.]./O3/69 ..... TANGENTIAL I~ETHO[:) HEASUEED. D_E.__~_L.A__T_L__g___,'_~_ ........................................ TOT~L CCORDXNATES ..... __C_L_.0 S.U R E S .... g-O~----L'E'~"~E~'IGN' DEPTH__ ANGLE ._I;IRECTI[)N ....... J'YD ._ SUB, SEA LATITUDE DEPARTURE DISTANCE ANGLE SEVERITY DISTANCE. Tv[; = t093.65, LATIfUDE = B.521 DEPARTURE = -10,17 .. 1205 ..... 9 ...... O' .......... N .... ~ ........ [2g~,28 ~097,08 25.88N I0,17W 27.81 N 21.45W O.000 21.07 ~.._t! __ O' ...N 0E 1327,.9~ .......... 12.21,!5 ........... 50,[~ ........ IO_..ITW .......... '.~_k~.3_3 N___1_!~47~_ .... ::': .... !..57~ ........... 43.95 148~ ....... 14 3a' ..... N ...... 1~ ........1476,98 1312,78 .. 8g. ITN 10,85W. 89.82 N 6,93W 2,247 80,59 .... 1617 _ 1~..~5~ __.N __6~ .......... 1657,95 1551,75 1~9,58N 4,50~ 149.65 N 1,72~ 2.~81 139,72 .... 188.9 ....... 20._30~_ _.N ..... 9E ........ L~_~_6,5Z 1750,32 . 222.91N 7 .... 20qb ..... 21 .... Q~ .....N .... 6~ ........~ig9 ..... 1896j89 ...... 278,87N 12 27~~_~1 .... O .......... N !E ...... 26~1,_41 2581.21 ' 539.38~ 46 __..t~ ........ :~_.30~ .......~ ..... '.~: ..... ~6...72 ........ 3580,~2 . _ ~~~._~ ~ .... N 1OE 3986,3'~.~_ ~ 0_,_~ .... 9 ~1.~_7 ~ N ......... 10_3 ~_ ~465 ...... 16 .. 0' _. N.. 82 .... 428~,24 4180,04 1066,94N 115 :. 4596 ....... 15..45'. NllE__ 44%2,33 ~306,13 1101,85N 122 : ..... .~.~ ...... 15_.45.' ....... N_.L~E ...... 472_8,97 4622.77 . [[89.51N "...5~01 .......2~ ..... 0j __N 17. f .... 50~_,~0 4976. ~0 ..... 1312.49N 176 _ '.5.~_69 2g ...... 0'_ ....... H _162 .... ~ 25_~t96_ _. 5!52,76 137~. 30N 194 _ 5799 19 0 ' N 21 E 5552 · 07 .......~_4~..5.._8.Z ..... ' 1 A~~..,._5.~ ....... 230 6005 ~8 O~ N_ ~32 ....... 5747.99 5641.79 1527.12N 255 0~17 ...... 16 lSJ. .N.252 ..........604.7.52 5941.32 .1606.25N 292 ~-6~1 ....... ~5 15j .... N 28. E ...... 6360.~2 6~53.92 1681.4~ 332 .%,.~21 .......... 18 30~_ ...... N_3LE ............ 6625,65 .700_6. _ 2.0 .._30! .... N .322 ...... ~705, ~.6 _~.069 __ 22 O' N 282 ....... 6763,68 7355 ...... 20. 30~.__ N .302..7031,56 ._. 7558 ......19 ._0 ~ ..... ~.3_~ ..... 7~3.50 6519.45 1757.65N 378 _ 6599,06 1782.89N 394 692~,36 1890.47N 455 7~17,30 1947.71k 488 __ ?_BBB .......... 18 . D' .. .N._31E ....... _7518,33 7412,13 2029,82N 537 __._BQSB .... 17 ........ 0~ ..... N__342 ............ ._7j/28._'12 _ . 7622,52 .... 2083. [SN 573 __.8_41.L .... 15__30: ..... N.._372 ....... 8.04_0.,_72 7940.52 ...... 2153.58N 626 ,lie 223,03 N 1.822 0.952 212,77 ,995 279.17 N 2.662 0.748 267,53 ,552 357.48 N 3.612 0,163 344,22 .642 541,39 N 4,942 0,143 52~,55 ,422 695,41 N 5,392 0,113 675,12 ,342 801,40 N 5,612 0.161 778,73 ,692 900,39 N 5,652 0,492 8'15.08 ,522 ........918,49_N..5,712 ..... 2.832 892,92 .492 g~7.22 N 6,01E 0,415 960,93 .4~E 10'13,17 N 6.1'12 0.176 1045,27 ,242 110~,61 N 6,332 0,654 1080.46 ,282 1197,64 N 6.672 O,OOO 1168,83 .882 1324,36 N 7.672 1,230 1297,33 .61E 1388.01 N 8.05E 0,181 1361.52 ,772 1486.55 N 8.93E 0.627 1462,40 .65E 1548.37 N 9.50E 0.574 1525,93 . · 54E 1632,67 N 10,322 0.591 1612.80 ,552 1714,07 N 11,182 0.397 1697.03 .312 1797,90 N 12.142 1.20l 1784.02 .CgE 1825,93 N 12.465 2,385 1813,06 .252 1944.52 N 13.532 0,582 1934.79 · 25E 2007,9~ N 14.07E 0.738 1999,73 __ .632 2099.82 N 14,832 0,338 2093,52 .6CE _._ 2.160.68 N 15,392 .........0.612 _.2155,73 .672 2242,90 N 16.222 0.520 2239,73 ........................................................... ~ E I..' L C ~ P P.L. T I C ~ R E P C R T ...... P~GE 2 - "-?ARA-THCIN-"._g-~-~_--~C?PANY D-;~O WELL COMPLETION RFT PP, EPAREC EY' SC's-:_ TANGENT[AL DEPTH__ ._ANGLE.__DIRECTION ......... TVD_ SU~ SEA LArlrU~E CEPARTL;RE ['IS1-ANCE ANGLE ..SEVERXTY DISTANCE . 86_/t~ ........ 15..30._~ _N 3LE ..... 8Z6_q. 32._ 8158.12 2ZO2.20N 663.2 ._.8755 ....... 16_.]O! ..... N_20E ......... B318.a7_ ...... 82b/~.67 __ 2231,11N 674.7 . _8886 ..... 18 ...... ~_' ...... N 20E ....... 8~95_,4~ 83.89.25 _. ZZ69.l. SN 688.6 _.. 9~L ...... 20.3.0.~ ....... N.2~ ........... 87Z~_, 9~_ 8618.7~ ....... Z31~.TIN 7Z0.7 .9~21 .... 17 .... 0~ N._2.~ .......... 8906..61 ...... 8800,~4. _. 2398.20N 7~5.9 7E 227~_"~7 N ].6.63E 0,567 .. 22.77.56 7E Z2Gg.'91 N 16.76E 3.161 2.297.71 5._E_ ......... ~_.~uL_Z_.~_7_?_N. I6.:_8_O..E....' .... ~ · 17..7_ ....... _2.. 3.1. 0., 6.~ CE Z37.!,33 N ].6,SEE 1.14.5 2369.27 6E ':._ Z~1.1.,§4 N 17,27E ..... 2,025 ._ 2510,02 2546.6~ ~32 .... .._9658 ..... l.g ..... 0 ....... N_.__2. E ............. ~Z2_~.,_96 ..... glide76 ......... 2495 27N .. IU21~ .... lg 45! ..... N _.32_E ........ 9_7_q 6~ 76 9640.56 ...... 2653.36N ..10~6 ..... 17 _~5' .... N__tSE ........100_~,16 .... 9920,56 . 2723.98N __l_g_ 30' ...... N_Z..(tE ......... 901_L~27 ........... 89_05.07 ....... 2430.92N 763.35E . 25~__7._.96 N_lT,43E._ 2,269 _ 19 O" N 29E 9077.q_.6_ ..... ._8_9_7_1,,~,_6.._ .Z_/t.~C_~_8_~_N' ......... 7.7~_.__!..0.E 2570.29 N 17.5_3_..E_ ..........._0_..__8_5_._5 ...... ..2569..!_1 , . ................. CLOSURE_ 2885.68 ....... N 19- 16' E 799.03E ..... 2620.,C8.._.N 17,75E .... 0.000 2619.t6 914.12E 2648...6l.__N _!7.90E ........ 0.723 ._ 2647.85 897.208 2800.94 N._lS.68E .... 0.176 2800.79 952.~SE 28e.5.~8 N..lg.Z7E ....... 0.944__. 2885.6B ......... .................. _iN_IERPQLATEE_VALUES FOR EVEN .... 100 FEET OF SUB SEA DEPTH · .__ DE_PTJL .................... T.VD ......... SLIB _.SE~ .... LATITUDE BEPARTURE DIFFERENCE ..... CORRECTION 1310 1306.20 . 1200.00____ 4fi ~.F.z~/_ ..... ,_~_0. ,. LT. W 4 1_4_1& .............. l~Ob..2.0 ....... .:3_(10.00 ........ 70,35N .......... -_lO, 52W 151L .................... 1506.20 ......... l_&O__O ._O 0 ..... 98,35N ........ ,9,88W ...... .... 1622_ .................. 160b,20 .......... /_50_0_,00_ .... 132, llN :L729_ ................... _1_~ 06.~20 ..... lbO0_.~O0 ........ 167,40N ]~8~: ............. 180t..2.l~ .... 17_00..(}_0 ...... 204.33N 204_9_ ................... 2006_.20 ....... 1900~_G_0 ....... 280,05N i~ .................... 21Q6-.2._0 .......... iO00..O0 ......... 318,15N 226_4~ .............220b._20 ........ 2_/A~O. O0 .......... 356,2.5N Z37_1 ................. 2306~.20 ...... 2200-~0 ....... 394,Z?N ... 2_4_"/_8. ._24Gb. 20_ ..... _23_~_,~ ......... 432o2.8N 2585 2506.20 2400.00 4_7. ~_ ~..4__N__ .... 2_fi9_2_ .............. _2606:2A1 ...... 25D0.00 ......... 508.44N 27.~ ............... 2706,_2Q ........... 260Q,_GO ....... .546,35N ~Q6_ ............. 2806,20 ....... 2700,C. 0 ..........:~B3°fl6N _3013._ .............. 2906,20 ..... 2 B_O_O~_O0 ....... 620,57N 56,61[: .... 312{1_ ............. ___3006_,2(~ .......2_900, O0 .... 657°68N ....... 61.165 _ . 3226 ...... 3106.20 3000.00 _(z9_~, ~_:~_N_.. _ _. 65,7_!_~-c. .................. ..... 3332 .............. 3206,20 .... ~/OO.~_O ¢ .......... 730,85N .__ 70,15E ....... 3~.39__ ................. 3306.20_ .........iP._O Q o .G:O ........... 766o9~N _. 74o5S~ ___3.5_45._ ................... 3~_06.,_20 __ 3_3.0_0,_0_0 802,67N 78.88E ~-"~. 3.? 5i ............ 3_606°?.0 ...... 35QOoQO 869o22N 85.87E 107 ............................... 7 .................................. 1~ ..................... 7 ......................... 12C 6 126_ ........................... .~. 133 .......................... ? 139 6 145 6 150 5 ~ . 3861 3lD6.20 3600,00 __. 9_01~8_9N ..... ..:___._8_9__:_62e ................ 15j~5 ............. 5 ............. ._ _3_gbf~ .............. 3BQ6,20 ...... 370.Q o_C_O ..... 930°91N ...... 94.52E 16C ............................... 5 ..... .6.0_7.0_ .............. _390.6_,.2D .......... ~8.OO_o.~O ...... 959,_LSN . _99,50E . 164 ...................._4 ..... 417_Z-L ............... ~C06,20 ........ 3.90_0_,_00 ..... 987,42.N. 104.28E 168 .................. ~ ............................. ...... 427_.R_ ............... 4106,20 ..... .40_00,_0~ .... 1015,82N __ 108,27E_. _ 1.72 ..................... 4 .................................. C R _T ....... PAGE DEPTH ............. "H ....................................................................EASUi~ED ............................ Tof-/~ E' COORD I N' ~'-i: 5'S DEPTH ............ TVO _ _ SUB SEA LATITUDE gEPAPTURE i~D_T¥0 .......... yERTiCAI~ ........... DIFFERENCE CORRECTION 4~86 _~306.20 4200..C0 .... LO_'._/'Zj_~_]7~N ......... 1 ~'~' . `459_0 ............ z~4_06,20 ....... `4300, OO 1 ].00, L~N 121,9LE 16q .... ~69~ ....... ~506,20 ....... ~O0,OO 1127,8~N 127,295 188 ..... ~7_~ ................... ~bQO, 2.0 ....... ~OQ~gO ..... ~155,b2N 132,68E 192 ~9~ ................. ~6.20 ......... ~6g.~gO ............. 118],.21N_ 1~8,C65 . . 195 ._~ '0~ .............~ b,2.Q ........ ~_70 Q,.GD .......... [216.,3'?N .... [~7.50E._ 201 ................................ 6 ................................ .......... 522.~ ............. .Sg_Qb,.ZQ. ......_,rt 9_Q.Q.. _C Q .......... 1286,00N_ 168,78E ....... 5 .,~J~ ................. 5_1_0_6.. 2.~ ........ .500.Q ..0_0_ ...... 1320,8~N _ J, 79,28E ..... 5~.3__ ............. 5206,20 ..... 5100_.,_0_0 _ . _ 1355,84N.. 189.316 ..... 5_53~ ............. _5.3.06,20 ........ 520.0.~0 ...... 1389,49N .... 200,43E .. 5751 ..5506.20 5400,CQ ___J,_~5.~.'L8_N ,...,. 5856 ............_5.606.20 ......... 55_Qg.00 ....... ].48~,,7XN 237o65E 596.L_ ........... 5.70_b.20 ...... ~60_O_._C 0 ...... ],51~., 62N ..... 250,3~ :._ .606~ .............. .580.6.20 ....... 5 :~QQ, O_Q ........ ].5/-t2, 50N 262,82 : ..... 6170_ ........... 59.06,20 5BO0.,.O0 ..... 1568,91N 215,14 _214 220 227 233 23~ 245 250 255 260 .................... 5 ............. 264 4 _ 6_27.~ .......... 6378 .6006.20 5900,00 1595,33N 287,~5E 268 6106.20 _. 6000.00 ...... [ ~?._Q_~;~.~N .... 3_C~ ,_ _~_5..~ ................... 272 __b ~t82._ ................ .6206.20 .......... ~. I_QO. ~:Q .....16/+4 o'~ ~fN ....... 6585 ................. _6306,20 .... 6200.00_ /668,51N 66_c20 ................... 6_406,20 ...... 6300°.gO__. [694.°71N k.,,,Z9~- ............. 6.506,20 .......... 6~00°_00 _ 1723.39N ...... 690.Q_ ................... 6606,20 ...... 650 Q_,.O 0 _ 1752 · 0TN 4 4 4 .. ~ 7007_. 6706,20 6600.00 17~,23N 394,2 ...... 711~ ................... 6~_06,20 ...... 6700,._00 ..~ 7221 ............ 6~g6,20 ._6800, O0 ....... X_8~9,88N _431.81E 7~2~ .............. .7006.20 ....... 6900.00 .... ~882.26N _450.50E .. 7~3~ ........... 7106.20 ...... 7000.0.0... 19X2.73N ..... 468,10E ._312.85E 276 325,65E 279 3~0,49E 264 357,73E 289 374.96E 294 6E 301 :]o8 ..................... 7 3t5 .............. 7 ............ 322 7 328 6 .............................. ~.E ~ L C C M P L E r I C h R E P O R T ........... PAGE_ 3 ........................... IN.TERPCLATE~ VALUES F£iR EVEN 100 FEET CF SUP SE~ DEPTH __MEA.StJR£D ..................................... TOTAL CPORCINATE$ . D EP ~J~ ..................... _]'.VD .......... ,SU!~... $.EA ......... LATITUDE I~EP,~R TUR E ~P-TVD ........... YERTICAL E[ FFEREtNCE CGRRECTI(]N 76~5 73~6 20 _ ? 2 00LC..~ ],_9_Z__O_.. ! R N ..... _5Q2.,_13r: ...... Z_750 .............. 74_Q6.2Q ...... 7~G.O.C.O ..... 199!~.59N 51E,86E ...... '/_85.5. ........... '/:506,20 ....... 75__00,_.G0 . . 2026.4qN 59~.~0E __796_0 ....... 7606.20 .... 7.50Q.00 2052.09N 5~2.65F ...... 806_~ ........ 7706.20 7600._00 2077,~N 569.75[ 339 5 344 5 349 5 354 5 358 4 81~.8 837b .... 8480 858~ .............. 8206.20 ...... 81_00,00 2188.38N . ~. 1t68_8 .......... 8306,20 _ ~200,~0 _ 2213,17M ~. 87~2 ......... 8406,2Q ..... 8~OO,~O .._ 2241.90N .~,, . 85~0 8400.00 ._ 90~ .......... ~.06.20 ......... eSOQ, OQ .... 2307.5~N .' .... 9[~ ................~706.20 ........ 860Q.C0._ . Z3AE.2[N 718 . ~216 ......... 8~_06..2Q ....... 87~.~0 _..2370.84N 732 ...... 9321 ............. 8906._20 ....... 88.0_0.0_0 .2398,08N _745 7806.20 ........ 7700.00 2100.31N 586 ._7_~.Q_6_,ZO .__~ 2122.45N ........ .8006.20 _ 7900.00 2144.60N 619 _81~6o20 _ 800.0,00 _ 2166,~3N 637 ~654 668 690 704 .53E 362 4 .91E 37C 4 ,45E 374 4 o96E 3'I~ 4 .ISE 382 4 ............ .68E 386 .............................. ,.lie _398 ,llE 405 .02~ 410 5 .90E 41~ .51E 421 6 ___9532 9106.20 9000,C0 ......... 9638 .................. 9_206.,20 ...... 9_/QO,gO _97~4 ............... 9306,20 ....... 9~0,00 ~_~85~ ............. 940_6.20 ........... ~3OO,.OO 2489.62N .795.~E ....... 2519.25N 813.43E 438 . 25~9.66N 832.41E 444 851.~3E 450 6 .. 9956 .................. 9~06,_Z0 .......... 9_~00.C0 _~. 2580. ].tN ................................................. __~',~,006~ __91; 0.6~2_0 ...... 95.{:)_0.00 ...... :~610.56N 870.46E 456 .................... 6 ................................. __~ 9706.20 9600.0~ , 26~ ~..QO.N 889.49E ..................4,6_3 ......................... 7 ............................................................. 1027~ ......... 9~0e..20 .... 9_7_00. CO 2668.35N 908.92E 468 '. 10.~ ............. ~906,_20 ....... ~8_00.00. '-_.2693,57N .... 928.63E 473 5 _., .......................................... IIXI'£~PO. LATED__VALUES FOR EVEN_IOOO_F~EI CF MEASURED. .OEP?H_ -M~-~U ~ O ..... TQTAL COOROINAIES MD-TVD VERTICAL . DEP~T.H ......... -"L~__~ ~T-'VD-_~__~_-~_._~UB'-'~-~ ..... LATITUDE ~EPaRTURE DIFFERENCE"'. ~.~' CORRECTION _A000 2 S 94,20 __~Q_0 ....... _~.16_,_l ~._N ............. 56 , 0 t E .................. 105 _ ~0D.0_ .............. 38~9,20 ..........3_733, C. 0 940.25N 96.17E ~ 160 _5000 ......... ~799,20 ..... ~693,00 _!214.04N 146.78E 200 6OOQ .............. 5743,2Q .... 563.7,00 1525.70N 255.06E 256 ..... 7..0~ ............. 66.99,20 ........ 659~,~0 _.1781.[[N ~2,9'?E 300 800_0 ............ ?6.~xt, 20_ ....... 7~_~8,._00 ..... 206%,82N ~59,21E 35.5 ......................... 55 ~_Z'9000 ...... 8602°20 8496, O0 __.~_3_.Q_.6_, [~._.N ~03.55E 397 62 ...1O.00Q .......... 9567,_2_Q ......... .9 ~t.6_[_,_00 2592.60N ..... 859,2Z, E ..... 652 ........................ 55 .............................. t t i ] . 1' '-- ,dO0' i FORM 369 ,4-63 · '*- ',' ,u .~.,~ UNION OIL COMPANY OF CALIFORNIA · FROM Union Oil Company "~.~] · Anchorage = AT TRANSMITTING THE FOLLOWING: ~ ~ DAILY WELL HISTORY MA~\THON TBUS D-20 --,, --. I -,. iqfi:q ,, ,,, ..... . ,,, UNION OIL & GAS DIVISION WESTERN REGION ANCHORAGE DISTRICT TO: STATE OF ALASKA TRANSMITTAL FROM- firaydon H. ggughbaum.., Jr.. DATE: 12-/1/69 WELL NAME.Marathon TBU D-20 & D-21 Transmitted herewith are the following: Run No. __ Fina_l__ Sepia Blue Scale Induction Electrical Log Dual Induction'Laterlog BHC SOnic/Caliper Log BHC Sonic/Gamma Ray BHC Sonic/Caliper/Gamma Ray Log Formation Sonic Log (Fs) Compensated Formation Density Formation Density Log (Fd) Neutron Log Formation Neutron Log (Fn) High Resolution Dipmeter (HDT) CDM Safety Print CDM or Printout CDM or Polywog Plot CDM Polar Plots Proximity blicrolog/Caliper Log Gamma Ray-Neutron Log Gamma Ray Collar Log Cement Bond Log Sidewall Neutron Porosity Log Laterlog 3 Mud log Core Descriptions, Conventional, No. Core Descriptions, Sidewall Core Analysis Formation Tests Directional Surveys Core Chips Sample Cut ~iVI$10N OF 011. AND GAS ANCHORAGE RECEIPT ACKNOWLEDGED' RETURN RECEIPT TO' Union Oil & Gas Division - Western Region Anchorage District P. O. Box 6247, Airport Annex Anchorage, Alaska 99503 ATTN: ROCHELLE CARLTON l~rm No. P--4 REV. 9-30-67 STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS WELL ~'ELL OTHER 2. NAME OF OP]~R. ATOR Union Oil gomoanv of California* 3, ADDRESS OF OPEI~ATOR - 2805 Denali Street, Anchorage, Alaska 99503 4. LOCATION OF Surface: 672.1' N, 1211.1' E from SW Corner Sec. 6-T8N-R13W-SM Prop. Prod. Zone: 1980' S, 2940' W from NE Corner Sec. 6-T8N-R13W-SM SUBMIT IN DUPLICATE %. AP1 NU~[ERICAL CODE 50-] 33-20203 LEASE DESIGNATION AND SEI~IAL NO. ADL 18729 T. IF INDIA]~, ALO'I IE~- O)~ TRIBE NAME 8. L~.'IT,F.~A{ OR LEASE N.~ME Tradinq Bay Unit 9. WELL NO. D-20 (22X-6) 10. FLF. J~D A_ND POOL. OR WILDCAT McA~th,m Ri ver n. SEC.. T.. R., ~.. (~O~O,~ HOLE OB.TF_,CTrv'E) Sec. 6-T8N-R13W-SM 12. PERMIT 1~O. 69-95 13. REPORT TOTAL DEPTH AT END OF MONTH, CI-IA~N'GES IN HOLE SIZE, CASING A.ND CE1VIENTING JOBS INCLUDING DEPTH SET AlXrD VOLLrNIES USED, PERFOtLATIONS, TESTS A/xrD R~ESULTS FISHING JOBS, JLrNK IN HOLE AND SIDE-TRACKED HOLE AN-D A~NY OTHER SIGNIFICANT CI-IA/NTGES IN HOL~ CONDITIONS. Trading B,ByI Unit D,20,_ October 1969 lO/1 - lO/15 Drilled and surveyed 12-1/4" hole from 6164' to 9678'. 10/16- 10/17 Drilled 12-1/4" hole from 9678' to 9748'; conditioned hole to run logs; ran logs; conditioned hole to run casing. 10/18- 10/19 Ran 9-5/8" casing, set at 9674' cemented with 2700 sacks cement Released rig to D-6 at 6-00 a.m., 10-19-69. 10t21 - 10/22 Released rig from D-6 to D-20 at lO:O0 p.m. (10-21,69); pressure tested casing and seal assembly with 2500 psi for 30 minutes; tested riser and BOP to 3500 psi; tested 9-5/8" casing to 2500 psi; all tests O.K.; drilled to 9788'. 10/23- 10/27 Drilled and surveyed 8-1/2" hole from 9788' to lO,506';.cleaned out bridges at 9745 9838, 9919' and 42' of fill; had tight hole at 10,440' 10,380', lO,OlO; cleaned out 3' of fill; conditioned hole to run logs; ran logs. ]0/28 Conditioned hole to run liner; ran 7" liner, shoe landed at 10,480', DV collar at 10,434' cemented with 300 sacks cement , · 10/29 Drilled and cleaned out cement to 10,430'; conditioned hole to run logs; loggfm§ tool failed in hole; ran 7" casing scrapper to 10,430'. 10/30 - lO/31 Ran cement bond log; perforated 7" liner with 4-1/2" holes per foot at 9750-9741'; attempted to run E-2 retainer, could not get into top of liner; milled out top of liner; ran and set retainer on wireline at 9500'; squeezed perforations at 9750-51 with 75 sacks cement. * Marathon Oil. ~ompany~ Suboperator, Bolly Varden Platform. with the Division of Mines & Mi~als bythe 15th of the succeeding month, unless otherwise directed. Form No, P--4 REV. STATE OF ALASKA SUBMrr n~ DU~LICA~ OIL AND GAS CONSERVATION COMMITTEE MONTHLY REPO'RT OF DRILLING AND WORKOVER OPERATIONS WELL WELL OTHER 2. NA2~IE OF OPERATOR Union 0il Company of California* 3. ADDRESS OF OPEI:~ATOR 2805 Denali Street, Anchora.qe, Alaska 99503 4. LOCATION OF WELL Surface: 672.1' N, 1211.1' E from SW Corner Sec. 6-T8N-R13W-SM Prop. Prod. Zone: 1980' S, 2940' W from NE Corner, Sec. 6-T8N-R13W-SM HLB ~ OKG ~ llJ · · 50-133-20203 K ADL 18729 --' -- 8. L.~IT,F.~A{ OR LEASE N.~E Trading Bay Unit 9. WET.T. NO. D-20 (22X-6) 10. ~'l~.u.~) A_~D POOL. OR '~VILDCAT McArthur Ri ver 11. SEC.. T., R., M.. (BO~I~OM HOLE OBJECrn~) Sec. 6-T8N-R13W-SM 12. PEB_NIIT NO. 69-95 13. REPORT TOTAL DEPTH AT END OF MONTH, CHANGES IN HOLE SIZE, CASING ANT) CE1VIENTING JOBS INCLUDING DEPTH SET AND VOLU'NIF~ USED, PERFORATIONS, TESTS A1N-D RESULTS. FISHING JOBS, JUNK IAI HOLE A_ND SIDE-T'R~CKED HOLE AND A~TY OTHER SIGNIFICA/NTT CI-LA/~GES IN HOL,~ CONDITIONS. Trading ..Bay Unit ..D.-20, September 1969 9/18 Moved rig to D-20 at l'00 p.m.; cleaned out conductor with 17-1/2" bit to 400'. 9/19 SpUdded well at 12-30 p.m. 9-19-69; drilled 17-1/2" hole from 400 to 789'. 9/20 - 9/22 Drilled and surveyed 12-1/4" hole from 789' to 3050'; opened 12-1/4" hole to 17-1/2" from 789' to 2350'. 9/23- 9/24 Opened 12-1/4" hole to 17-1/2" hole from 2350' to 3050'; conditioned hole to run casing; ran 13-3/8" casing, landed shoe at 3006'; cemented casing with 2400 sacks cement. Released rig at 3'00 a.m. 9-24-69 to move to D-4. 9/26 - 9/27 Moved rig from D-4 to D-20 at 3:00 p.m. 9-26-69. Tested casing with 1000 psig; tested BOPs with 3000 psig; drilled float collar and shoe; drilled 12-1/4" hole from 3050' to 3904'. 9/28 - 9/~0 Drilled and surveye~ 12-1/4" hole from 3904' to 6164'. DIVISION OF OiL ~. GA~I ~4. I hereby SIGNED * Marathon 0il Company, Suboperator, Dolly Varden Platform. ~ ~A~ 10/13/69 each calendar month, regardless of the status of operations, and must be filed in duplicate ' ials by the 15th of the succeeding month, unless otherwise directed. . ( ~l.~/:~'l'~ II I~V, Mi NOTE--I~:obrt on (his ~orm ij required for with the Division of Mines & Mira October 6, 1969 Mr. Wade S. McAlister Landman Union Oil Company of California 2805 Denal i Street Anchorage, Alaska 99503 FILE Re: Trading Bay Unit, D-20 Union Oil Company of California Operatm~ Dear Mr. McAlister: In reference to the subject offShore drill-site the following' stipulations are required to protect fish and game resources: 1. No material foreign to the environnient will be discharged from this platform. This includes garbage, trash, refuse, petroleum and/or its products, drilling mud, and debris. 2. Oil industry operations in this area are not'to interfere with colwnerc.i al fishing. 3. The Habitat Biologist'.s Office: lO.iS=West International Airport Road, Anchorage, Alas!ca 99502 will 'be notified on completion of the subject drilling operation. Statement: The foregoing provisions do not relieve the lessee and/or his contractors or assignees of any responsibilities or provisions required by law or regulation of the State of Alaska or the Federal Government~ RJI,~': bb cc: Hilliker Denton Burrell ?.r:? 71969 VIVi~ON OF OIt ANP OlVl:~ ~ OIL ~ ~ Trading Ray Unit No. I)-20 Enct~ fs t~e ~pFove~. ,a~l'fcatl~a to ~t;1t ~ above iieT1 ~I~ en~ ~ ~, ~ 'not, re~f~, a ~.eec, tt~l ~ hal:e,. Form P--1 REV. 9-3~gl SUBMIT IN TRI ATE (Other instructions on reverse side) STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE , APPLICATION FOR PERMIT TO DRILL, DEEPEN, OR PLUG BACK la. TYPE OF WORK DRILL ~] DEEPEN F-1 PLUG BACK []] TYPE OF WELL WELL WELL OTHER ZONE ZONE 2. NANIE OF OPEIq~TOR *Union 0il Company of California 3. ADDi:LESS (TF OPERATOR 2805 Denal i Street 4. LOCATIOATO~ WELLAt sur£ace Cond. q Leg B-i 672. I'N, 1211 . I'E from SW corner Section 6, T.8N., R. 13W., SM At proposed prod. zone1980'S, 2940' W from NE corner Sec. 6, T8N, R13W, SM 13. DISTANCE IN MILES AND DIRECTION F£~OM NEAREST TOWN OR POST OFFICE* 21 miles northwest of Kenair, Alaska 14. BOND INFOi:LIViATION: Uni ted-Paci fic Insurance Co. ~t~tewide Surety an,/or No. B-55502 15. DISTANCE FROM PROPOSED* LOCATION TO NEAREST PROPERTY OR LEASE LINE, FT. (Also to nearest drig, unit, if ~ny) 1980' 18: DISTANCE FROM PROPOSED LOCATIO'N* TO NEAREST WELL DRILLING, COMPLETED. OR APPLI~ FOR, FT. 2250' from D-3 21. ELEVATIONS (Show whether DF, RT, CR,.etc.) ' 106 RI Mean Sea Level i16. NO. OF ACRES IN LEASE 3085.00 1§' pRoPosE3Z) DEPTH !' TVD ]0,045 MD 10,500' PI 50-133-20203 5, 6. LEASE D]~SIGNATION AND S]~IAL NO. ADL 18729 ?. IF INDIAN, ALLO'i-r~:s: OR TRIBE NAME S. UNIT~ FAI~VE OR LEASE NAM~ Tradino Bay Unit g. lAq~LL NO. '~ 8-20 (22X-6) 10. FIELJZ) AND POOL, OR Vv'ILDCAT McArthur Ri vet (Hemlock) ii. SEC.-, T., R., ~., (BO~O~ ROLE O~.CTIV~.) 6, T8N, R13W, SM 12. ~.o,,-~ .il tiff. 00fl. 00 17. NO. ACRES ASSIGNED TO ~%~IiS WE'LL 160. O0 23. !:.'"" PI~O,POSE:D CASING AND CEMENTING PROGRANi . , 20. ROTARY OR CABLE TOOLS Rotary ~. APPROX.. DATE WORK WILL START* Sept 30, 1969 Blowout Preventer Program - Install 20" 2000# hydril atop 33" conductor through 20" 600 Series riser. Test kill line.and choke manifold~w/2000#. Install & test 13-3/8" 5000 psi Cameron Type U doublegate, 5000 psi choke manifold and kill line with 3000 psi after 13-3/8" is set. Use same BOP hookup for 9-5/8". Test same with 5000 psi. Use same BOP for 7" liner. ,17" /4" ~13-3/8" '"'' 61# ~'" ~'J~55 2500 ' l~~ .... 12-I 95-/8" ~. ,, 47~. N-80 9800 2400 sacks. 8-112" 7" 29¢, N-80 ~I~ 300 ~ack~ , , ~ ..., Bottom hole location 1782' S, 2879' W from NE corner Section 6, T8N, R13W, SM *Marathon 0il Company - Sub-operator - Dolly Varden Platform I'N ABOVE SP~CE DESCRIBE,PRO,POSED PROGRA1VI: If ~po~l is ~ dee~n or plug ~ck, give ~ on present p~du.~ive ~ ~d propo~ new produ~ive ~e, Ii pro,~ is ~ drill or d~n d~ect ~onally, give pe~ent ~ on ~bs~a~ ~t~ns ~d mea~4 ~d ~ue ve~ical dept. Give blo~ut preventer program. 24. I hereb~ertify that the~rego~ is ~e~ ~e~ (This space for State office use) J [] YES KNO SAMPLES AND CORE CHIPS REQUIRED CONDITIONS OF APPROVAL, IF ANY: tA.P.I. 1TDME~CAL CODE [DIF-ECTIONAL SURVEY 17~EI~UIt~ . XTM [] NO Please see transmittal l~tt.~ ..... APPROVAL DATE ':,. Chairman *See InstructiOns On Reverse Side 9/26/69 DATE 9/26/69 ,32 594 ! _ Pr!BHL TMD 10~500 TVD 10,0,45~3 D-.20 /. UNIO N-MA R,ATH DOLLY VARD D-1'7 D 5 ..... ~ (44-6) I .4- 1 D-14 (44-7) J8 \ \ \ \\\\\\ D-16 (12X-1~7) .\ U-M ADL 18729 PPSS D-8 (24-8) J7 D-21 "b (24x-17) ADL 17579 T9N R 13W ' T RI3W , -o_+2L o` , T8N TD 11,281' D-19 (22-4) D-lO (44 -5) UNION WELL LOCATION MAP MARATHON SUB-OPERATOR TRADING BAY STATE UNIT D-20 (22X-6) 0 2000 SCALE: I"= 2000'' I .... ; 19'69. CHECK LIST FOR NEW WELL PERMITS Company //~.,, L~ ~, Lease & Well No. %'~.~. ~D-~ Yes No Remarks 1 Is well to be located in a defined pool .... - .... ,~Y~L 2 Do statewide rules apply 3. Is a registered survey plat attached ...... ,..~"~ .... $. · iS We,, '°c ted Proper !'[ani~ ~;om proper3~ i;n! ::..i. )'' a 'di an -. 1: ':' ..~4', ':' Is well located proper d 6'~'¢!i ?~::~i~:iS' Sufficient Undedicated:'"adreage ~aVailabie this pool":~: ::~' :' :7,...,': Is well to be deViated`. '8'; s operator the only affected party . 9'~":'~'~,;:"~an pemtt be approved before ten-day wait - . , ~ ........ , , . DOeS operator have a bond in force ...... -, , .,., , ,. ...... . ~ ......_? . . . . 1~, _I~ ~nou~h cement u~ed to c~rculate on conductor ~nd ~urface , , .., :'~ :': '..: :.: ' :' ,:.~ , ~' .. ' . , . . . . 1. )Will c~ent tie in Surface and tnte~ediate or:ProductiOn strings . 14, ~ill cmen~ cover all possible productive horizon~ ...... 15, ~tll ~urface ca~ing cover all fresh ~ater zones , , ~ .... .16, ~11 ~urface c~. ~nternal bur~t equal ,5 p~/ft, to next 17, ~11 all ca~tn~ ~ive adequate ~afet7 ~n collapse and tension ...... 18. ~oe$ BOP[ have ~uffic~ent pressure rat~n~ ............... ~dd~ gional Requirements: ......