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Home My WebLink About168-073Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www.aogcc.alaska.gov December 22, 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-11 PTD 1680730 Dear Mr. Marlowe: On June 2, 2025, an Alaska Oil and Gas Conservation Commission (AOGCC) Petroleum Inspector witnessed a no-flow test of Trading Bay Unit D-11 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 1 hour shut in period to monitor pressure build up followed by a short flow period through the test equipment to an open top tank – repeated 2 additional times. Initial gas rates were 500 scf/hr and fell to zero within about 4 minutes. There was no oil flow rate observed during the no-flow test. Trading Bay Unit D-11 may be produced without a subsurface safety valve as confirmed by the AOGCC Inspector at the conclusion of 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-11 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 cc: P. Brooks AOGCC Inspectors James B. Regg Digitally signed by James B. Regg Date: 2025.12.24 09:55:40 -09'00' 2025-0602_No-Flow_TBU D-11_ss Page 1 of 3 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg DATE: 6-14-2025 P. I. Supervisor FROM: Sully Sullivan SUBJECT: No Flow Test Petroleum Inspector Dolly Varden D-11 Hilcorp Alaska LLC PTD 1680730 6-2-2025: Traveled to the Dolly Varden Platform to witness a no-flow test on well Trading Bay Unit D-11. The well has been open to atmosphere for 44 hours prior to testing. The tubing and inner annulus (IA) were in communication with a 1-inch hose manifold. There were calibrated gauges on the tubing and IA. Hilcorp chose to use the 1-hour build up method and demonstrated 2 consecutive pressure build periods that had 0 fluid discharge and no more than 500 scf/hour. Neither the tubing nor the IA ever rose above 0 psi. The following table shows test details: Time Pressures1 Remarks Tubing IA OA 0748 0.0 0.0 28 Shut-in for pressure build 0803 0.0 0.0 28 0818 0.0 0.0 28 0833 0.0 0.0 28 0848 0.0 0.0 28 0849 0.0 0.0 28 Open to flow; Initial 0 scf/hr 0850 0.0 0.0 28 Shut-in for pressure build 0905 0.0 0.0 28 0920 0.0 0.0 28 0935 0.0 0.0 28 0950 0.0 0.0 28 0951 0.0 0.0 28 Open to flow; initial 500 scf/hr 0955 0.0 0.0 28 0 scf/hr; End test 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: Operator Reports; Test Instrument Calibrations        2025-0602_No-Flow_TBU D-11_ss Page 2 of 3 No-Flow Test – TBU D-11 (PTD 1680730) Photos by AOGCC Inspector S. Sullivan 6/2/2025 2025-0602_No-Flow_TBU D-11_ss Page 3 of 3 Logs (List logs and submit electronic and printed data per tal Depth measured STATE OF ALASKA feet feet ALASKA OIL AND GAS CONSERVATION Junk Baker TE -5 SCSSV COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Abandon U Suspend ❑ Plu Perforations 9 Fracture Stimulate Pull Tubing Packer for Redrill ❑ PerforateLi ❑ Other Stimulate El Alter Casing 11Plug Perforate New Pool ❑ Operator king Repair Well ElRe-enterSusp Well El?. Jame: Hilcorp Alaska, LLC 4. Well Class Before Work: 5. Parr I. Address: 3800 Centerpomt Ddve, Suite 1400 Development ❑✓ Exploratory 11168-07 Anchorage, AK 99503 Stratigraphic ElService Q 6. API 1 Logs (List logs and submit electronic and printed data per tal Depth measured 11,514 feet feet true vertical9-feet Junk Baker TE -5 SCSSV active Depth measured 10,957 feet Packer true vertical 9,478 feet king Length Size Structural 8,884 feet Conductor -400' 33" Burst Surface 2,511' 13-3/8" -400' Intermediate Production 9,691• 95/81, 3,090 psi Liner 2,074• 7" 8,455' nation depth Measured depth 10,325 - 11,390 feet 11,514' True Vertical depth 8,97 feet ig (size, grade measured and t Operations shutdown Change Approved Program ❑ Other: n b0-733-20140-00-00 Name and Number. Bay Unit D-11 i/Pool(s): 1r River Field / Hemlock Oil & Middle Kenai G Oil Pools Plugs 2-7/8" measured N/A feet Motl D Perm Pkr Junk Baker TE -5 SCSSV measured 10,840 feet Packer measured 10,210 feet true vertical 8,884 feet MD TVD Burst Collapse -400' -400' 2,511' 2,349' 3,090 psi 1,540P si 9.691' 8,455' 5,750 psi 3,090 psi 11,514' 9,905' 8,160 psi 7,020 psi me vertical depth) 2-7/8" 6.5 / L-80 10,250 (MD) depth) and SSSV (type, measured and true vertical de P ) Motl D Perm Pkr 10,210 (MD) 8,884 (ND) Baker TE -5 SCSSV wlabon or cement squeeze summary: treated (measured): nt descriptions including volumes used and final pressure: Prior to well operation: 74 Subsequent to operation 63 ltachments (required per 20 AAC 25.070, 25.071, & 25.283) Report of Well Operations 0 s of Logs and Surveys Run ❑ d and Electronic Fracture Stimulation Data ❑ lereby certify that the foregoing is true and correct to Stan W. Golfs Operations Manager Form 10-404 Revised 4/2017 _) // 1, / .I / or 49 g Pressure 1156 8,916 (TVD) 392 (MD) 392 (TVD) --•-•r u unveiopmentLService ❑ Stratigraphic El Status after work: 'TOR ❑ WINJ ❑ WAG E01GINJ Oil ❑ Gas ❑ WDSPL ;t of m kn0wled e. ❑ SUSP ❑ SPLUG y 9 Sundry Number or N/A if C.O. Exempt: 319-335 Contact Name: Dan Marlowe q Contact Email: dmariowefd)hilcom Wm Date: 1 S Contact Phone: (907) 283-1329 RBDMS A46 0 5 2019 ZVb117 Submit O ginal Only ff Hil.p Alaska, LLC RKB to MSL = 106.90' 1 2 3 4 5 6 7 8 9 10 11 M 12 13 15 N G-1 G-3 G-4 ght G-5 spot @ SCHEMATIC SIZE -13" WT GRADE ID Conductor Item 13-3/8" 61 K-55 9-5/8" 40 N-80 43.5 N-80 47 N-80 47 RS -95 7" 29 N-80 2.441" 4.750" GLM #1- SFO -1 Gas Lift Mandrel, BK -2 Latches 2-7/8" 6.5 L-80 2.441" 4.750" GLM#2-5FO-1 Gas Lift Mandrel, BK -2 Latches McArthur River Field, TBU Well # D-11 PTD: 168-073 API: 50-733-20140-00 As Completed: 01/14/2014 ETAIL INN I ID TOP BTM. Butt. LT&C EUE 8.681 8.681 6.184 NO. Death TVD ID OD Item 43' of wireline tool, 7/10/1999 @ 30,957' BUM P (MD) BTM (MD) TOP (TVD) Tubing Hanger 1 SPF DATE 2.312" 4.625" 555V - Baker TE- 5, Lockout tool instal led 02/12/2018 2 8,978' ' 2.441" 4.750" GLM #1- SFO -1 Gas Lift Mandrel, BK -2 Latches 3 06 2.441" 4.750" GLM#2-5FO-1 Gas Lift Mandrel, BK -2 Latches 4 5 ' 2.441" 4.750' GLM #3 -SFO-1 Gas Lift Mandrel, BK -2 Latches 5 5,408' 4,747' 2.441" 4.750" GLM #4 -SFO -1 Gas Lift Mandrel, BK -2 Latches 6 6,009' 5,267' 2.441" 4.750" GLM #5 - SFO -1 Gas Lift Mandrel, BK -2 Latches 7 6,547' 5,749' 2.441" 4.750" GLM #6 -SFO -1 Gas Lift Mandrel, BK -2 Latches 8 7,116 6,259' 2.441" 4.750" GUM #7 -SFO -1 Gas Lift Mandrel, BK -2 Latches 9 7,686' 6,752' 2.441" 4.750" GLM #8 -SFO -1 Gas Lift Mandrel, BK -2 Latches 10 8,287' 7,263' 2.441" 4.750" GLM #9 - SFO -1 Gas Lift Mandrel, BK -2 Latches it 8,856' 7,757' 2.441" 4.750' GLM #10 -SFO -1 Gas Lift Mandrel, BK -2 Latches Open 9,459' 8,264'1299992- 11,154' 9,509 GLM #11- SFO -1 Gas Lift Mandrel, BK -2 Latches 156' 1 10,061' 8,761' Open B-5 GLM #12 -SFO -1 Gas Lift Mandrel, BK -2 Latches (Orifice) K17 10,201' 8,876'X 30' N-0 Nipple Open 10,210 8,884' 11,390 9,755 Packer 70 10,241' 8,909'X Open Nipple 10,250 8,916'WLEG Fish Tagged @ 16.27' eline tool string w/magna range plug (unset) 08/26/19 @ ±10,840' ELM 21' of Wireline tools, 12/2/92 @ 11,185' WLM 43' of wireline tool, 7/10/1999 @ 30,957' BUM Updated by: JLL 08/26/2019 PERFORATION DETAILS P (MD) BTM (MD) TOP (TVD) BTM (TVD) AMT SPF DATE Present Condition 325' 10,362' 8,978' 9,008' 37' 6 08/24/19 Open 06 10,443 9,044 9,073 27 5 01/07/14 Open 58 W10,90210,985 10,487 9,086 9,109 23 5 01/07/14 Open 98 10,566 9,118 9,173 55 5 01/07/14 Open 44 10,671 9,235 9,256 21 5 01/07/14 Open 86 10,730 9,268 9,302 34 5 01/07/14 Open 02 10,985 91436 9,499 83' 6 3/1989 Open B-4 10,998' 11,154' 9,509 9,627 156' 1 6 3/1989 Open B-5 11,220 1 11,250 9,601 1 9,701 30' 6 3/1989 Open 6-6 11,320 11,390 9,755 9,809 70 2 10/1975 Open Updated by: JLL 08/26/2019 KHilcorp Alaska, LLC Hilcorp Alaeka>LLC Well Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date Trading Bay Unit D-11 Eline 50-733-20140-00-00 168-073 8/22/2019 8/27/2019 Daily Operations: 08/22/2019-Thursday Arrive @ heliport. Wait on weather and wildfire smoke. Arrive on platform. Hold orientation and PJSM. Scope out work area. Stage and spot equipment. M/U GR, CCL and 10' of 1.75" geo 5.1 g HMX Razor Charge 6 SPF 60 degree phasing. CCL is 8' above top shot. Pressure test lubricator to 250 psi low/ 1500 psi high per AOGCC approved sundry. RIH, have production cut back G/L to get dwn hole. Check up weights every 1000'. Encounter heavy up weight @ 9500', confirm w/ town. Check up weights @ 10,000', 10,400' and 10,800'. Log up from 10,800' to 10,100'. Send correlation to town, 22' feet high. Correct correlation and re-send to town. Correlation good. Correlate and park on depth. Perf. 30' of G-01 sand from 10,352-10,362'. No chg in tb pressure=102 psi. POOH- all shots fired. M/U 10' of 1.75" geo 5.1 g HMX Razor Charge 6 SPF 60 degree phasing guns, CCL is 8.25' above top shot. RIH to 10,500'. Attempt to log up for correlation, guns hung up. Work guns until they came free at 3200 PUW. Work guns into tubing. Attempt to clean hole by running in 50' at a time, and run into PUW's over 3000 lbs. Decision made to POOH, night cap well, and SDFN. 08/23/2019 - Friday Hold PJSM, fill out PTW. M/U 10' of 1.75" geo 5.1 g HMX Razor Charge 6 SPF 60 degree phasing. CCL is 8.2' above top shot. Re-head tool. RIH, start taking up weights at 8000' every 500'. At 10,000' take up weights every 100'. PUW ranging 2600-3000 Ib. Work tool string from 10,450' to 10,200' to clean up. PUW 2600 Ib. Make several correlation passes, correlate on depth. Perf G-01 sand from 10,342'-10352'=10'. Tb press. =100 psi, no change. POOH- all shots fired. Tubing pressure increased from production choke packing off w/ scale. Re-head tool string. M/U 10' of 1.75" geo 5.1 g HMX Razor Charge 6 SPF 60 degree phasing. CCL is 8.2' above top shot. RIH, correlate on depth. Perf G-01 sand from 10,332-10,342=10'. Tb pressure = 150 psi, no change. POOH- all shots fired. M/U 7' of 1.75" geo 5.1 g HMX Razor Charge 6 SPF 60 degree phasing. CCL is 11' above top shot. RIH, correlate on depth. Perf G-01 sand from 10,325' to 10,332'= 7'. Tb pressure= 150 psi, no change. POOH- all shots fired. Turn well over to production and let them bring it around to flush out scale and attempt to drop a G/L valve. M/U Magna Range Plug (permanent) Plug, RIH w/ plug. Unable to correlate w/ CCL, POOH. M/U new CCL and RIH. Unable to correlate, POOH. See fluid level @ 3,250'. Re-head , check and clean all connections in tool. R/U new CCL tool. RIH, get hung up @ 10,063.9' (GLM # 12). Work tool up to 3250 Ib PUW. Get tool moving downhole, get hung up at 10,153.4'. Have production bring on well. Work tool up to 3250 PUW. No joy. Lay down crew. 08/24/2019-Saturday PTW and PJSM. Work tool up to 3200 Ib PUW w/ well flowing, no joy. Continue to work tool up to 3200 Ib PUW. Pump water down tubing, up to 1500 psi. No joy. Operations pressured up well w/ GL, attempt to bring on well hard. No joy. Decision made to drop cutter bar. Hold PJSM meeting w/ E-Line, Pollard Slickline and Production. Drop 1.66" OD Kinley Braided Line Cutter @ 18:38. Work line up and down every 5-10 minutes to assist cutter falling down cable. Line cut @ 19:42. POOH- recover all E-Line cable, and line cutter. R/D all equipment and send E-Line crew to beach. THE STATE OIALASKA GOVERNOR MIKE DUNLEAVY Stan Golis Operations Manager Hilcorp Alaska, LLC. 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Alaska Oil and Gas Conservation Commission Re: McArthur River Field, Hemlock Oil and Middle Kenai G Oil Pool, Trading Bay Unit D-11 Permit to Drill Number: 168-073 Sundry Number: 319-335 Dear Mr. Golis: 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fox: 907.276.7542 www.aogcc.alaska.gov Enclosed is the approved application for the sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, V7� Daniel T. Seamount, Jr. Commissioner fk DATED this Z. of July, 2019. RBDMSA'-/ JUL 2 6 2019 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 �IECP VE JUL 17 2019 DTs 7 / L 40 1. Type of Request: Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Repair Well ❑ Operations shutdown ❑ Suspend ❑ Perforate 0 Other Stimulate ❑ Pull Tubing ❑ Change Approved Program ❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other: ❑ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Hilcorp Alaska, LLC Exploratory ❑ Development Q • Stratigraphic ❑ Service ❑ 168-073 ' 3. Address: 3800 Centerpoint Drive, Suite 1400 6. API Number: Anchorage, AK 99503 50-733-20140-00-00 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 Trading Bay Unit D-11 9. Property Designation (Lease Number): 10. Field/Pool(s): ADL0017594 McArthur River Field / Hemlock Oil & Middle Kenai G Oil Pool 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): 11,514 9,905 10,957 9,478 -1300 psi N/A 10,957 Casing Length Size MO TVD Burst Collapse Structural Conductor -400' 33" -400' Surface 2,511' 13-3/8" 2,511' 2,349' 3,090 psi 1,540 psi Intermediate Production 9,691' 9-5/8" 9,691' 8,455' 5,750 psi 3,090 psi Liner 2,074' 7" 11,514' 9,905' 8,160 psi 7,020 psi Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 10,406 -11,390 9,044 - 9,809 2-7/8" 6.5 / L-80 10,250 Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): Mod D Perm Pkr & Baker TE -5 SCSSV 10,210 (MD) 8,884 (TVD) & 392 (MD) 392 (TVD) 12. Attachments: Proposal Summary Q 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: 7/30/2019 OIL WINJ ❑ WDSPL ❑ Suspended ❑ GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ 16. Verbal Approval: Date: Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. 1 hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name: Stan W. Golis Contact Name: Dan Marlowe Authorized Title: Operations Manager Contact Email: dmarlowe@hilcorp.com c, \ , Contact Phone:(907)283-1329 Authorized Signature:-�`1+�••� w Date: � (p dry COMMISSION U E ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 14 S Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: pp Post DMS --v JUL 2 6 2019 Initial Injection MIT Req'd? Yes ❑ E]RBNo Spacing Exception Required? Yes No Subsequent Form Required: ❑ APPROVED BY ''7 'f �/ p/ /( 4�`�� ` Approved by: COMMISSIONER THE COMMISSION Date: ! /` �/,1.t•�l1 �l 0vRUGlo ' [�' Submit Forth and Forth 10-403 $�Wfsed•41201 l 111 Abproved appliWtio I tiit��iii��rrrj�i��iCCC a of ppprovval eachments in Duplicate K ltil.q Alk., LLC Well Work Prognosis Well Name: Trading Bay Unit D-11 API Number: 50-733-20140-00 Current Status: Producer (Gas Lift) Leg: Leg #A-2 (NW corner) Estimated Start Date: July 30, 2019 Rig: E -Line Reg. Approval Req'd? 403 Date Reg. Approval Rec'vd: Regulatory Contact: Juanita Lovett Permit to Drill Number: 168-073 First Call Engineer: Dan Marlowe Office: 907-283-1329 Cell: 907-398-9904 Second Call Engineer: Stan Golis Office: 907-777-8356 Cell: 281-450-3071 Current Bottom Hole Pressure: 3,347 psi @ 9,044' TVD 0.370 lbs/ft (7.12 ppg) Maximum Expected BHP: 3,347 psi @ 9,044' TVD 0.370 lbs/ft (7.12 ppg) Maximum Potential Surface Pressure: ^'1,300 psi Gas Lift header pressure **No Flow well as of 01/18/2018 Brief Well Summary This well was worked over in January 2014 and completed as a gas -lifted producer. This project will add new perforations in the G-0 & G-1 sands. Procedure: 1. MIRU E -line, PT lubricator to 1,500 psi Hi 250 Low. 2. RU a -line guns and perforate G -zone 3. RD E -line. 4. Turn well over to production. 5. Conduct no -flow test or reactivate and test SSSV within 14 days Attachments: 1. Current Well Schematic 2. Proposed Well Schematic H Uiloorp Alaska, LLC RKB to MSL = 106.90' 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 G-3 G-4 Tight G-5 pot C toss - 9-5/8" 47 McArthur River Field, TBU LT&C Well # D-11 SCHEMATIC PTD: 168-073 N-80 API: 50-733-20140-00 6.184 As Completed: 01/14/2014 TOP (TVD) CASING DETAIL CE WT GRADE CONN ID TOP BTM. Conductor I Surf "400' "1 61 1 K-55 I Butt. LT&C 1 12.515 1 Surf 2.511' 47 RS 11 LT&C 8.681 8,21 29 N-80 8rd LT&C 6.184 9,44 TOP (TVD) Tubing Hanger TUBING DETAIL 392' 392' 6.5 L-80 I 8rd EUE 2.441 Surf 2,150' 2.441" 4.750" GUM #1 -SFO -1 Gas Lift Mandrel, BK -2 Latches 3 NQ' Depth MD Death TVD ID OD Rem 41' 41' BTM (MD) TOP (TVD) Tubing Hanger 1 392' 392' 2.312" 4.625" SSSV - Baker TE -5, Lockout tool installed 02/12/2018 2 2,266' 2,150' 2.441" 4.750" GUM #1 -SFO -1 Gas Lift Mandrel, BK -2 Latches 3 3,911' 3,462' 2.441" 4.750" GLM #2 - SFO -1 Gas Lift Mandrel, BK -2 Latches 4 4,839' 4,258' 2.441" 4.750" GLM #3 - SFO -1 Gas Lift Mandrel, BK -2 Latches 5 5,408' 4,747' 2.441" 4.750" GLM #4 - SFO -1 Gas Lift Mandrel, BK -2 Latches 6 6,009' 5,267' 2.441" 4.750" GLM #5 - SFO -1 Gas Lift Mandrel, BK -2 Latches 7 6,547' 5,749' 2.441" 4.750" GLM #6 - SFO -1 Gas Lift Mandrel, BK -2 Latches 8 7,116' 6,259' 2.441" 4.750" GLM #7 -SFO -1 Gas Lift Mandrel, BK -2 Latches 9 7,686' 6,752' 2.441" 4.750" GLM #8 - SFO -1 Gas Lift Mandrel, BK -2 Latches 10 8,287' 7,263' 2.441" 4.750" GLM #9 - SFO -1 Gas Lift Mandrel, BK -2 Latches 11 8,856' 7,757' 2.441" 4.750" GLM #10 - SFO -1 Gas Lift Mandrel, BK -2 Latches 12 9,459' 8,264' 2.441" 4.750" GLM #11- SFO -1 Gas Lift Mandrel, BK -2 Latches 13 10,061' 8,761' 2.441" 4.750" GLM #12 -SFO-1 Gas Lift Mandrel, BK -2 Latches (Orifice) 14 10,210' 8,884' 4.000" 5.813" Packer 15 10,241' 8,909' 2.813" 4.500" %Nipple 16 10,250' 8,916' 2.992" 4.500" WLEG Fish Tagged @ 21' of Wireline tools, 12/2/92 @ 11,185' WLM 43' of wireline tool, 7/10/1999 @ 10,957' BUM Updated by: DEM 02/12/2018 PERFORATION DETAILS ZONE TOP (MD) BTM (MD) TOP (TVD) STM (TVD) AMT SPF DATE Present Condition G-3 10,406 10,443 9,044 9,073 27 5 01/07/14 Open G-4 10,458 10,487 9,086 9,109 23 5 01/07/14 Open G-4 10,498 10,566 9,118 9,173 55 5 01/07/14 Open G-5 10,644 10,671 9,235 9,256 21 5 01/07/14 Open G-5 10,686 10,730 9,268 9,302 34 5 01/07/14 Open B-1,3 10,902 10,985 9,436 9,499 83' 6 3/1989 Open B-4 10,998' 11,154' 9,509 9,627 156' 6 3/1989 Open B-5 11,220 11,250 9,601 9,701 30' 6 3/1989 Open B-6 11,320 11,390 9,755 9,809 70' 2 10/1975 Open Updated by: DEM 02/12/2018 H Ililcuru Alaeka, LLC 1.7 McArthur River Field, TBU Well d D-11 PROPOSED PTD: 168-073 SIZE API: 50-733-20140-00 As Completed: 01/14/2014 CASING DETAIL WT GRADE I CONN ID TOP BTM. 13-3/6 1 bl I K-55 G-0 1 12.515 1 Surf 2,511' G-1 40 N-80 Buttress G-3 Surf 5,238' 9-5/8" G-4 N-80 Buttress 8.755 G-5 Tight 2.441" 47 spot @ Buttress 8.681 loss _ 8,215- 4.750" McArthur River Field, TBU Well d D-11 PROPOSED PTD: 168-073 SIZE API: 50-733-20140-00 As Completed: 01/14/2014 CASING DETAIL WT GRADE I CONN ID TOP BTM. 13-3/6 1 bl I K-55 I Butt. LT&C 1 12.515 1 Surf 2,511' 41' 40 N-80 Buttress 8.835 Surf 5,238' 9-5/8" 43.5 N-80 Buttress 8.755 5,238' 6,760' 2.441" 47 N-80 Buttress 8.681 6,760' 8,215- 4.750" 47 RS -95 LT&C 8.681 8,215' 9,691' 7" 29 N-80 Bird LT&C 6.184 9,440' 11,514' 6 6,009' 5,267' TUBING DETAIL 4.750" GLM #5 - SFO -1 Gas Lift Mandrel, BK -2 Latches 7 2-7/8" 6.5 L-80 I 8rd EUE 2.441 1 Surf 10,250' 6,259' 2.441" 4.750" GLM #7 -SFO -1 Gas Lift Mandrel, BK -2 Latches 9 7,686' 6,752' NU. Depth MD Depth TVD ID OD Item 41' 41' BTM(MD) TOP (TVD) Tubing Hanger 1 392' 392' 2.312" 4.625" SSSV-Baker Ti Lockout tool installed 02/12/2018 2 2,266' 2,150' 2.441" 4.750" GUM #1 -SFO -1 Gas Lift Mandrel, BK -2 Latches 3 3,911' 3,462' 2.441" 4.750" GLM #2 -SFO -1 Gas Lift Mandrel, Bli Latches 4 4,839' 4,258' 2.441" 4.750" GLM #3 - SFO -1 Gas Lift Mandrel, Bli Latches 5 5,408' 4,747' 2.441" 4.750" GLM #4- SFO -1 Gas Lift Mandrel, BK -2 Latches 6 6,009' 5,267' 2.441" 4.750" GLM #5 - SFO -1 Gas Lift Mandrel, BK -2 Latches 7 6,547' 5,749' 2.441" 4.750" GLM #6 - SFO -1 Gas Lift Mandrel, Bil Latches 8 7,116' 6,259' 2.441" 4.750" GLM #7 -SFO -1 Gas Lift Mandrel, BK -2 Latches 9 7,686' 6,752' 2.441" 4.750" GLM #8 -SFO -1 Gas Lift Mandrel, BK -2 Latches 10 8,287' 7,263' 2.441" 4.750" GLM #9 -SFO -1 Gas Lift Mandrel, BK -2 Latches 11 8,856' 7,757' 2.441" 4.750" GLM #30 - SFO -1 Gas Lift Mandrel, BK -2 Latches 12 9,459' 8,264' 2.441" 4.750" GLM #11 -SFO -1 Gas Lift Mandrel, BK -2 Latches 13 10,061' 8,761' 2.441" 4.750" GLM #12 -SFO -1 Gas Lift Mandrel, BK -2 Latches (Orifice) 14 10,210' 8,884' 4.000" 5.813" Packer 15 10,241' 8,909' 2.813" 4.500" X Nipple 16 1 10,250' 8,916' 2.992" 4.500" WLEG Fish Tagged @ 21' of Wireline tools, 12/2/92 @ 11,185' WLM 43' of wireline tool, 7/10/1999 @ 10,957' BUM Updated by: JUL 07/09/2019 PERFORATION DETAILS ZONE TOP(MD) BTM(MD) TOP (TVD) BTM (Ti AMT SPF DATE Present Condition G-0 ±10,291' ±10,309' ±8,950' ±8,965' ±18' Future Proposed G-1 ±10,325' ±10,362' ±8,978' ±9,008' ±37' Future Proposed G-3 10,406 10,443 9,044 9,073 27 5 01/07/14 Open G-4 10,458 10,487 9,086 9,109 23 5 01/07/14 Open G-4 10,498 10,566 91,118 9,173 55 5 01/07/14 pen G-5 10,644 10,671 9,235 9,256 21 5 01/07/14 pen G-5 10,686 10,730 9,268 9,302 34 5 01/07/14 pen B-1,3 10,902 10,985 9,436 9,499 83' 6 3/1989 pen [open B-4 10,998' 11,154' 9,509 9,627 156' 6 3/1989 pen B-5 11,220 11,250 9,601 9,701 30' 6 3/1989 pen B-6 11,320 11,390 9,755 9,809 70' 2 10/1975 Updated by: JUL 07/09/2019 ti OF r • I ��s THE STATE Alaska Oil and Gas wI1—„ � . — �' Of L sKA Commission�®nS�rVatlCommissionSSI®n 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 7 Main: 907.279.1433 OF ALASY'ts Fax: 907.276.7542 www.aogcc.alaska.gov January 24, 2018 Mr. Stan Golis Operations Manager—CI Offshore Hilcorp Alaska, LLC P.O. Box 244027 Anchorage, AK 99524-4027 RE: No-Flow Verification S C NNE Trading Bay Unit D-11 PTD 1680730 Dear Mr. Golis: On January 18, 2018 an Alaska Oil and Gas Conservation Commission (AOGCC) Petroleum Inspector witnessed a no-flow test of Trading Bay Unit D-11 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-11 prior to the test. The well performance was monitored for three hours. Gas flow rates at the end of three separate flow checks preceded by 1- hour pressure build up periods were initially observed to be 1000 standard cubic feet per hour, declining to zero within 15 seconds. There was also no liquid flow to surface during the no-flow test. Trading Bay Unit D-11 may be produced without a subsurface safety valve. A fail-safe automatic surface safety valve system capable of preventing uncon r 11ed 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-11 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, .1,.(11- '-e.'po James B. Regg7 Petroleum Inspection Supervisor ecc: P. Brooks AOGCC Inspectors • II' MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg DATE: 1/19/2018 P. I. Supervisor FROM: Adam Earl SUBJECT: No Flow Test Petroleum Inspector TBU D-11 Hilcorp Alaska LLC PTD 1680730 1/18/18: I traveled out to Trading Bay Unit Dolly Varden platform to witness a No-Flow Test to be conducted by lead operator, Christy Anderson. The well to be tested was D- 11 - a gas lift production well. I walked down the rig-up, the well, and lines coming off. The well had been opened to bleed down to zero for at least the last 36 hours. The test consisted of shutting in the well and monitoring pressures every 30 mins. The tubing would be opened to flow through a certified no-flow meter(measuring in standard cubic feet per hour, SCFH) on the hour, 3 consecutive times. The following table shows test details: Time Pressures' Flow Rate2 Remarks (psi) Gas-scf/hr Liquid -gal/hr 12:45 0/0/16 0 0 Well shut in 13:15 0.16/1/16 0 0 Well shut in 13:45 0.31/1/16 1000 0 Opened to meter; started at 1000 scfh; 0 scfh in 10sec. 14:15 0.19/1/16 0 0 Well shut in 14:45 0.35/1/16 1000 0 Opened to meter; started at 1000 scfh; 0 scfh in 10sec. 15:15 0.22/1/16 0 0 15:45 0.39/1/16 1000 0 Opened to meter; started at 1000 scfh; 0 scfh in 15 sec; no liquid to surface 1 Pressures are T/IA/OA 2 Gas flow not to exceed 900 scf/hr; Liquid flow not to exceed 6.3 gal/hr There was no liquid production during the flow test periods. TBU D-11 exhibits the characteristics for approval of the no-flow test. Attachments: Photos SCANNED l; Test Equipment Certifications 2018-0118_No-Flow_TBU_D-11_ae.docx Page 1 of 3 • • • IIII Ili i aa cc . n m � u • ,i,_i co - v �, U d d ti '2 ''Ar" Z En 4111 n LL -o bA 04k y U o 00 o , .`* CI o oq IN . o wa z 1 o Z 00 U o 'N Ocl o r0. EL ¢ 041 co Q w , m I . U $ . mss, � t. O o — r : o O N LL +� a O co o � � zap • • . U M `.l (1 I Z O c Q, Ov w b _ Si N N a F � U �� N NI o If W>< � t� o n .. 1 rt _ O r= g NI v .b I I w MM to m X w p pI �I N <�el0 al ., W 8 O ,1.9ji pp }yf +q a) (L tA �' �y p, r N M ;�, . F �]T�i CC I A N CC F c N b Q ., ,w..t a. a O z d il 61 ar ,-.IU n ifi S 5- S, e h Jam..A i 0 ti a. ;a E w en = 4. "goE o r/ 6. ��M w a: O Zio o0 0 N 0 \ x -c7,r-' MN , _ Fiem to r- CZ co (:1 Tai cc h aC p Mi 1 p 10118 I S Q ..... U th it ~ m Ct yi y bA }t: w 2 F s p-, ESD U Schwartz, Guy L (DOA) From: Schwartz, Guy L (DOA) Sent: Monday, January 26, 2015 9:23 AM To: 'Juanita Lovett' Cc: Dan Marlowe; samantha.carlisle@alaska.gov Subject: RE: Withdraw Sundry: D-11 - PTD 168-073 - Sundry # 314-527 Juanita , AOGCC will withdraw sundry 314-527 as requested. Guy Schwartz Senior Petroleum Engineer AOGCC 907-301-4533 cell 907-793-1226 office SCANNED ,IAN 2 7 2015 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 (Guy.schwartz@olaska.aov). From: Juanita Lovett [mailtoJovett@hilcorp.com] Sent: Monday, January 26, 2015 8:52 AM To: Schwartz, Guy L (DOA) Cc: Dan Marlowe Subject: Withdraw Sundry: D-11 - PTD 168-073 - Sundry # 314-527 Guy, Please withdraw the above mentioned sundry. Thank you, Juanita Lovett Operations/Regulatory Tech Hilcorp Alaska, LLC 3800 Centerpoint Drive Suite 1400 Anchorage, AK 99503 Office: (907) 777-8332 Email: ilovett@hilcorp.com 0"73 THE STATE ��ld--'ka�G ii end 07 of 1b 11s Dan Marlowe GOVIiRNOR SEAN PARNELL Operations Engineer Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: McArthur River Field, Hemlock Oil and Middle Kenai G Oil Pools, Trading Bay Unit D-11 Sundry Number: 314-527 Dear Mr. Marlowe: 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276-7542 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. DATED this eday of September, 2014. Encl. Sincerely, Cathy P. Foerster Chair NEED STATE OF ALASKA �5 C% APPLICATION ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25280 RECEIVED SEP 2 4 2014 AOGCC 1. Type of Request: Abandon ❑ Plug for Redrill ❑ Perforate New Pool ❑ Repair Well ❑ i 5 2`, �� til ►y Change Approved Program ❑ Suspend ❑ Plug Perforations ❑ Perforate 0 Pull Tubing ❑ Time Extension ❑ Operations Shutdown ❑ Re-enter Susp. Well ❑ Stimulate ❑ Alter Casing ❑ Other. ❑ 2. Operator Name: 4. Current Well Gass: 5. Permit to Drill Number: Hilcorp Alaska, LLC - Exploratory ❑ Development Stratigraphic ❑ Service ❑ 168-073 3. Address: 6. API Number: 3800 Centerpoint Drive, Suite 1400, Anchorage AK, 99503 50-733-20140-00 , 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 21J Trading Bay Unit D-11 ' 9. Property Designation (Lease Number): 10. Field/Pool(s): ADLO17594 McArthur River Field / Hemlock Oil Pool, Middle Kenai G 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): 11,514 9,905 10,957 9,478 N/A 10,957 (Fish) Casing Length Size MD TVD Burst Collapse Structural Conductor Surface 2,511' 13-3/8" 2,511' 2,349' 3,090psi 1,540psi Intermediate Production 9,691' 9-5/8" 9,691' 8,455' 5,750psi 3,090psi Liner 2,074' 7" 11,514' 9,905' 8,160psi 7,020psi Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): See Attached Schematic / See Attached Schematic 2-7/8" 6.5# / L-80 10,250 Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): Model D Perm Packer / SSSV 10,210'(MD) / 8,884'(TVD) and 392'(MD) / 392(TVD) 12. Attachments: Description Summary of Proposal Q 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic ❑ Development ED' Service ❑ 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: 10/1/2014 Oil F±1• Gas ❑ WINJ ❑ GINJ ElWAG WDSPL ❑ Suspended ❑ 11Abandoned ❑ 16. Verbal Approval: Date: N/A Commission Representative: N/A GSTOR F-1SPLUG E] 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Dan Marlowe Email dmarlowe hilcor .com Printed Name Dan M lowe Title Op erations Engineer Signature L�. Phone (907) 283-1329 Date 9/24/2014 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: Spacing Exception Required? Yes ❑ No Subsequent Form Required: /Q — APPROVED BY /9;�� 9 Approved by: COMMISSIONER THE COMMISSION Date: �� OFOUINAL RBCMS OCT -1201" Submit Form and Form 10-403 (Revised 10/2012) Approved application is valid for 12 months from the date of approval. Attachments in Duplicate HilrArp Alaska, LIX Well Work Prognosis Well: D-11 Date: 09/24/14 Well Name: Trading Bay Unit D-11 API Number: 50-733-20140-00 Current Status: Producer (Gas Lift) Leg: Leg #A-2 (NW corner) Estimated Start Date: October 01, 2014 Rig: E -Line Reg. Approval Req'd? 403 Date Reg. Approval Rec'vd: Regulatory Contact: Juanita Lovett Permit to Drill Number: 168-073 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: — 3,400 psi @ 9,186' TVD/11,100 MD 0.37 psi/ft., (7.0 ppg) at mid-perf of all perfs Max. Expct'd BHP: — 3,400 psi @ 9,186' TVD/11,100' MD 0.37 psi/ft., (7.0 ppg) Max. Possible SP: —1,350 psi gas -lift header pressure Brief Well Summary This well was worked over in January 2014 and completed as a gas -lifted producer. This project will add new perforations in the G-1 & G-2 sands. Procedure: 1. MIRU Slick -line, PT lubricator to 1,500 psi Hi 250 Low. 2. RIH with slick -line gauge ring to +/-10,400'. 3. RIH with dummy guns to +/-10,400'. 4. RD Slick -line. 5. MIRU E -line, PT lubricator to 1,500 psi Hi 250 Low. 6. RU a -line guns and perforate G -zone (Proposed perfs shown on the proposed schematic in red font) 7. RD E -line. 8. Turn well over to production. Attachments: 1. Current Well Schematic 2. Proposed Well Schematic McArthur River Field, TBU SCHEMATIC Well # D-11 As Completed: 01/14/14 Hilcorn Alaska, LLC RKB to TBG Head = 106.90' Tree connection: 4-1/6" 5.000# 1 2 3 4 5 6 7 8 9 10 11 C TI 13 12 13 14 15 46 G-3 G-4 Tight G-5 spot @ 10855' _ B-1 0 :':':':'. . . :.....:........:::::: B-3 B-3 B-5 B-6 PBTD = 11,425'TD = 11,514' MAX HOLE ANGLE = 42°, KOP @ 400' CASING AND TUBING DETAIL Depth LMAD ID Item SIZE WT GRADE CONN ID TOP BTM. 13-3/8" 61 K-55 Butt. LT&C 12.515 Surf 2,511' 9-5/8" 40 N-80 Buttress 8.835 Surf 5,238' 9-5/8" 43.5 N-80 Buttress 8.755 5,238' 6,760- 9-5/8" 47 N-80 Buttress 8.681 6,760' 8,215' 9-5/8" 47 RS -95 LT&C 8.681 8,215' 9,691' 7" 29 N-80 8rd LT&C 6.184 9,440' 11,514' Tubing: SFO -1 Gas Lift Mandrel, BK -2 Latches 13 10,061' 2.441" SFO -1 Gas Lift Mandrel, BK -2 Latches (Orifice) 14 2-7/8" 6.5 L-80 8rd EUE 2.441 Surf 10,250' NO. Depth LMAD ID Item Tubing Hanger 1 392' 2.313" SSSV 2 2,266' 2.441" SFO -1 Gas Lift Mandrel, BK -2 Latches 3 3,911' 2.441" SFO -1 Gas Lift Mandrel, BK -2 Latches 4 4,839' 2.441" SFO -1 Gas Lift Mandrel, BK -2 Latches 5 5,408' 2.441" SFO -1 Gas Lift Mandrel, BK -2 Latches 6 6,009' 2.441" SFO -1 Gas Lift Mandrel, BK -2 Latches 7 6,547' 2.441" SFO -1 Gas Lift Mandrel, BK -2 Latches 8 7,116' 2.441" SFO -1 Gas Lift Mandrel, BK -2 Latches 9 7,686' 2.441" SFO -1 Gas Lift Mandrel, BK -2 Latches 10 8,287' 2.441" SFO -1 Gas Lift Mandrel, BK -2 Latches 11 8,856' 2441" SFO -1 Gas Lift Mandrel, BK -2 Latches 12 9,459' 2.441" SFO -1 Gas Lift Mandrel, BK -2 Latches 13 10,061' 2.441" SFO -1 Gas Lift Mandrel, BK -2 Latches (Orifice) 14 10,210' 4.000" Packer 15 10,241' 2.81" X Nipple 16 10,250' 2.992" WLEG Fish Tagged @ 21' of Wireline tools, 12/2/92 @ 11,185' WLM 43' of wireline tool, 7/10/1999 @ 10,957' BLM Updated by: JILL 02/17/14 PERFORATION DETAILS ZONE TOP (MD) BTM (MD) TOP (TVD) BTM (TVD) AMT SPF DATE Present Condition G-3 10,406 10,443 9,044 9,073 27 5 01/07/14 Open G-4 10,458 10,487 9,086 9,109 23 5 01/07/14 Open G-4 10,498 10,566 9,118 9,173 55 5 01/07/14 Open G-5 10,644 10,671 9,235 9,256 21 5 01/07/14 Open G-5 10,686 10,730 9,268 9,302 34 5 01/07/14 Open B-1,3 10,902 10,985 9,436 9,499 83' 6 3/1989 Open B-4 10,998' 11,154' 9,509 9,627 156' 6 3/1989 Open B-5 11,220 11,250 9,601 9,701 30' 6 3/1989 Open B-6 11,320 11,390 9,755 9,809 70' 2 10/1975 Open Updated by: JILL 02/17/14 McArthur River Field, TBU Proposed Well # D-11 As Completed: 01/14/14 Hilcorp Alaska, LLC, RKB to TBG Head = 106.90' Tree connection: 4-1/6" 5.01 M Tight spot @ 10855' 1 2 3 4 5 6 7 8 9 10 11 12 13 14 5 16 G-1 G-2 G-3 G-4 G-5 : B-1 o :•:•:•:•:•:•:•::.:.:: B-3 B-3 .............. .............. .............. B-5 B-6 PBTD = 11,425'TD = 11,514' MAX HOLE ANGLE = 421, KOP @ 400' CASING AND TUBING DETAIL Depth MS ID Item 43' of wireline tool, 7/10/1999 SIZE WT GRADE CONN ID TOP BTM. 13-3/8" 61 K-55 Butt. LT&C 12.515 Surf 2,511' 9-5/8" 40 N-80 Buttress 8.835 Surf 5,238' 9-5/8" 43.5 N-80 Buttress 8.755 5,238' 6,760' 9-5/8" 47 N-80 Buttress 8.681 6,760' 8,215' 9-5/8" 47 RS -95 LT&C 8.681 8,215' 9,691' 7" 29 N-80 8rd LT&C 6.184 9,440' 11,514' Tubing: SFO -1 Gas Lift Mandrel, BK -2 Latches 13 10,061' 2.441" SFO -1 Gas Lift Mandrel, BK -2 Latches (Orifice) 14 2-7/8" 6.5 L-80 8rd EUE 2.441 1 Surf 10,250' NO. Depth MS ID Item 43' of wireline tool, 7/10/1999 @ 10,957' BLM Tubing Hanger 1 392' 2.313" SSSV 2 2,266' 2.441" SFO -1 Gas Lift Mandrel, BK -2 Latches 3 3,911' 2.441" SFO -1 Gas Lift Mandrel, BK -2 Latches 4 4,839' 2.441" SFO -1 Gas Lift Mandrel, BK -2 Latches 5 5,408' 2.441" SFO -1 Gas Lift Mandrel, BK -2 Latches 6 6,009' 2.441" SFO -1 Gas Lift Mandrel, BK -2 Latches 7 6,547' 2.441" SFO -1 Gas Lift Mandrel, BK -2 Latches 8 7,116' 2.441" SFO -1 Gas Lift Mandrel, BK -2 Latches 9 7,686' 2.441" SFO -1 Gas Lift Mandrel, BK -2 Latches 10 8,287' 2.441" SFO -1 Gas Lift Mandrel, BK -2 Latches 11 8,856' 2.441" SFO -1 Gas Lift Mandrel, BK -2 Latches 12 9,459' 2.441" SFO -1 Gas Lift Mandrel, BK -2 Latches 13 10,061' 2.441" SFO -1 Gas Lift Mandrel, BK -2 Latches (Orifice) 14 10,210' 4.000" Packer 15 10,241' 2.81" X Nipple 16 10,250' 2.992" WLEG Fish Tagged @ 21' of Wireline tools, 12/2/92 @ 11,185' WLM 43' of wireline tool, 7/10/1999 @ 10,957' BLM Updated by: JLL 09/24/14 PERFORATION DETAILS ZONE TOP (MD) BTM (MD) TOP (TVD) BTM (TVD) AMT SPF DATE Present Condition G-1 ±10,291 ±10,305' ±8,950' ±8,962' ±14' Future G-2 ±10,327' ±10,360' ±8,980' ±9,007' ±33' Future G-3 10,406 10,443 9,044 9,073 27' S 01/07/14 Open G-4 10,458 10,487 9,086 9,109 23' S 01/07/14 Open G-4 10,498 10,566 9,118 9,173 55' S 01/07/14 Open G-5 10,644 10,671 9,235 9,256 21' S 01/07/14 Open G-5 10,686 10,730 9,268 9,302 34' S 01/07/14 Open e-1,3 10,902 10,985 9,436 9,499 83' 6 3/1989 Open B-4 10,998' 11,154' 9,509 9,627 156' 6 3/1989 Open B-5 11,220 11,250 9,601 9,701 30' 6 3/1989 Open B-6 11,320 11,390 9,755 1 9,809 70' 2 10/1975 Open Updated by: JLL 09/24/14 RECEWED STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION FB 18 2014 REPORT OF SUNDRY WELL OPERATIONS r 1. Operations Abandon ❑ Repair Well ❑ Plug Perforations ❑ Perforate [�] Other 0 Clean Out/ Run Gas Lift Performed: Alter Casing ❑ Pull Tubing❑✓ Stimulate - Frac ❑ Waiver ❑ Time Extension❑ Change Approved Program ❑ Operat. Shutdown❑ Stimulate - Other ❑ Re-enter Suspended Well❑ 2. Operator 4. Well Class Before Work: 5. Permit to Drill Number: Name: Hilcorp Alaska, LLC Development [A Exploratory ❑ Stratigraphic❑ Service ❑ 168-073 3. Address: 3800 Centerpoint Drive, Suite 1400 6. API Number: Anchorage, AK 99503 50-733-20140-00' 7. Property Designation (Lease Number): 8. Well Name and Number: ADL17594 Trading Bay Unit / D-11 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pool(s): McArthur River Field / Hemlock Oil Pool, Middle Kenai G Oil 11. Present Well Condition Summary: Total Depth measured 11,514 feet Plugs measured N/A feet true vertical 9,905 feet Junk measured 10,957' (fish) feet Effective Depth measured 10,957 feet Packer measured 10,210 feet true vertical 9,478 feet true vertical 8,884 feet Casing Length Size MD TVD Burst Collapse Structural Conductor Surface 2,511' 13-3/8" 2,511' 2,349' 3,090 psi 1,540 psi Intermediate Production 9,691' 9-5/8" 9,691' 8,455' 5,750 psi 3,090 psi Liner 2,074' 7" 11,514' 9,905' 8,160 psi 7,020 psi Perforation depth Measured depth See Schematic feet True Vertical depth See Schematic feet Tubing (size, grade, measured and true vertical depth) 2-7/8" 6.5# / L-80 10,250' (MD) 8,915' (TVD) 10,210' (MD) 392' (MD) Packers and SSSV (type, measured and true vertical depth) Model D Perm Pkr 8,884' (TVD) SCSSV 392' (TVD) 12. Stimulation or cement squeeze summary: Intervals treated (measured): R6DMS MAY 11 2014 Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 0 0 1275 120 Subsequent to operation: 20 0 132 930 110 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run Exploratory❑ Development❑ . Service ❑ Stratigraphic ❑ Daily Report of Well Operations X 16. Well Status after work: Oil • 2] Gas ❑ WDSPL❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP❑ SPLUG❑ 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 1313-464 Contact Dan Marlowe Email dmarlowe_@hilcorp.com Printed Name Dan Marlowe Title Operations Engineer Signature �ji„V Phone (907) 283-1329 Date 2/17/2014 Form 10-404 Revised 10/2012 �� '� Submit Original Only Ililcoru Alaska, LLC RKB to TBG Head = 106.90' Tree connection: 4-1/6" 5.01 C M 12 T 13 14 15 46 G-3 G-4 Tight G-5 Spot @ - '% f 10855' DMD B-1 : o . tem SIZE WT tom' B-3 i ID TOP B-3 13-3/8" 61 B-5 ............. Butt. LT&C 12.515 B-6 PBTD 9-5/8" = 11,425'TD = 11,514' N-80 Buttress MAX HOLE ANGLE = 420, KOP @ 400' 9-5/8" 43.5 N-80 Buttress 8.755 5,238' 6,760' 9-5/8" 47 N-80 Buttress 8.681 10 8,215' O 1 47 1 LT&C 8.681 8,215' 11 ■ C M 12 T 13 14 15 46 G-3 G-4 Tight G-5 Spot @ - '% f 10855' SCHEMATIC McArthur River Field, TBU Well # D-11 As Completed: 01/14/14 CASING AND TUBING DETAIL DMD B-1 : o . tem SIZE WT GRADE B-3 i ID TOP B-3 13-3/8" 61 B-5 ............. Butt. LT&C 12.515 B-6 PBTD 9-5/8" = 11,425'TD = 11,514' N-80 Buttress MAX HOLE ANGLE = 420, KOP @ 400' SCHEMATIC McArthur River Field, TBU Well # D-11 As Completed: 01/14/14 CASING AND TUBING DETAIL DMD ID tem SIZE WT GRADE CONN ID TOP BTM. 13-3/8" 61 K-55 Butt. LT&C 12.515 Surf 2,511' 9-5/8" 40 N-80 Buttress 8.835 Surf 5,238' 9-5/8" 43.5 N-80 Buttress 8.755 5,238' 6,760' 9-5/8" 47 N-80 Buttress 8.681 6,760' 8,215' 9-5/8" 47 RS -95 LT&C 8.681 8,215' 9,691' 7" 29 N-80 8rd LT&C 6.184 9,440' 11,514' Tubing: SFO -1 Gas Lift Mandrel, BK -2 Latches 13 10,061' 2.441" SFO -1 Gas Lift Mandrel, BK -2 Latches (Orifice) 14 2-7/8" 6.5 L-80 8rd EUE 2.441 1 Surf 10,250' NO. DMD ID tem Tubing Hanger 1 392' 2.313" SSSV 2 2,266' 2.441" SFO -1 Gas Lift Mandrel, BK -2 Latches 3 3,911' 2.441" SFO -1 Gas Lift Mandrel, BK -2 Latches 4 4,839' 2.441" SFO -1 Gas Lift Mandrel, BK -2 Latches 5 5,408' 2.441" SFO -1 Gas Lift Mandrel, BK -2 Latches 6 6,009' 2.441" SFO -1 Gas Lift Mandrel, BK -2 Latches 7 6,547' 2.441" SFO -1 Gas Lift Mandrel, BK -2 Latches 8 1 7,116' 2.441" SFO -1 Gas Lift Mandrel, BK -2 Latches 9 7,686' 2.441" SFO -1 Gas Lift Mandrel, BK -2 Latches 10 8,287' 2.441" SFO -1 Gas Lift Mandrel, BK -2 Latches 11 8,856' 1 2.441" SFO -1 Gas Lift Mandrel, BK -2 Latches 12 9,459' 2.441" SFO -1 Gas Lift Mandrel, BK -2 Latches 13 10,061' 2.441" SFO -1 Gas Lift Mandrel, BK -2 Latches (Orifice) 14 10,210' 4.000" Packer 15 10,241' 2.81" 1 X Nipple 16 10,250' 2992" 1 WLEG Fish Tagged @ 21' of Wireline tools, 12/2/92 @ 11,185' WLM 43' of wireline tool, 7/10/1999 @ 10,957' BLM Updated by: JILL 02/17/14 PERFORATION DETAILS ZONE TOP (MD) BTM (MD) TOP (TVD) BTM (TVD) AMT SPF DATE Present Condition G-3 10,406 10,443 9,044 9,073 27 5 01/07/14 Open G-4 10,458 10,487 9,086 9,109 23 5 01/07/14 Open G-4 10,498 10,566 9,118 9,173 55 5 01/07/14 Open G-5 10,644 10,671 9,235 9,256 21 5 01/07/14 Open G-5 10,686 10,730 9,268 9,302 34 5 01/07/14 Open B-1,3 10,902 10,985 9,436 9,499 83' 6 3/1989 Open B-4 10,998' 11,154' 9,509 9,627 156' 6 3/1989 Open B-5 11,220 11,250 9,601 9,701 30' 6 3/1989 Open B-6 11,320 11,390 9,755 9,809 70' 2 10/1975 Open Updated by: JILL 02/17/14 Hilcorp Alaska, LLC I I ileorp Alaska, LLC Well Operations Summary Well Name JAPI Number lWell Permit Number Start Date End Date D-11 50-733-20140-00 168-073 1 12/13/2013 1/14/2014 Daily Operations: 12/13/13 - Friday Rigging up. 12/14/13 -Saturday Rigging up. 12/15/13 -Sunday Pull riser and remove 5' spool and add (2) 4' sections. Land risers, flow cross, double BOP and Hydril. Torque up all bolts on riser and 12/16/13 - Monday Continue testing BOP's to 250 low 3000 high and annular to 250 low 3000 high on chart for 5 min. _3- failures. IBOP valve on circ manifold & HCR valve on choke line leaked on high test, function valves and retested ok, all test done from main Koomey unit, functioned remote. Jim Regg, AOGCC, waived witness at 08:23 hrs. 12/16/13. Blew down lines and manifolds, pulled test jts, broke out cross overs and ported sub. MU landingjts land and make up same into hanger. Back out hanger hold down pins. PU 37k and pulled hanger free. Continue pulling hanger to rig floor, pipe wt. = 33k. Attempted to fill hole with 100 bbl. of FIW w/o success, blew down lines, B/0 landingjts and hanger, laid out same. Stabbed TIW and close same. Closed Hydril to shut in well. Continue POOH with 3-1/2" eue 8rd tbg. Off load 3-1/2" work string from work boat. Continue POOH with 3-1/2" 8rd production tbg. Off load E -line unit from work boat. Continue POOH with 3-1/2" 8rd production tbg. Total tbg recover = 99 jts, (1) GLM & (1) Sub Surface Safety Valve, total length = 3,176.32'. 12/17/13 -Tuesday Service rig and have pre job JSA on picking up and making up fishing tools. PU & MU BHA #1, 8-1/8" OD hollow mill guide 8-1/8" OD extension, 8-1/8" OD overshot with 3-1/2" grapple, 6-1/2" OD top bushing, 4-1/2" IF x 3-1/2" IF x -over, 4-3/4" bumper & oil jar, (4) 4- 3/4" drill collars, 3-1/2" PH -6 box x 3-1/2" IF pin x -over Total length = 152.25'. Install 13-5/8" x 7-1/16" DSA on top of upper riser spool. RIH with 3-1/2" PH -6 work string & BHA#1 strapping and rabbiting same. Tagged top of 3-1/2" production tbg @ 3,223' PM spaced out work string, PU and RU power swivel. Slack off to top of fish, pumping at 2 bpm, rotating @ 50 rpm with 1,000 ft. /lb. of torque, tagged fish torque increased to 2,000 ft. /lb., mill down 6" & torque dropped to 1,000 ft. /lb., stopped rotating, slacked off and sat 10K down on fish, pulled 3' and had no over pull attempted to latch ten additional times w/o success. L/0 power swivel & POOH to surface with overshot. BO & LO overshot and inspect same, found ID of hollow mill guide to be roughly 3-11/16" Contacted Knight Oil Tools and they did not have another one in stock. Cleaning and servicing rig while waiting on Knight to build another guide 12/18/13- Wednesday Continue doing cleaning rig winterizing while waiting on Knight tools to arrive. MU BHA #2 -8-1/8" hollow mill guide with 3-1/2" ID, 8- 1/8" overshot with 3-1/2" grapple , 4-3/4" bumper and oil jars, (4) drill collars, 3-1/2" PH -6 x 3-1/2" IF x -over, total length = 152.25'. RIH to 3,200' with BHA #2 and 3-1/2" PH -6 work string & rig up power swivel.. Break circ with 1/2 bpm @ 81 psi, dress off top of fish rotating @ 60 rpm 2k -3k down on mill. Slacked off 4' and tagged up with 15k down, PU 10' with no over pull, slacked off 13', PU 20' with no over pull. RD power swivel, Blow down lines. POOH to surface with BHA #2, shuck over shot from top of fish. BO and LO 2 jts of 3-1/2" 8rd production tbg length = 62.59' new top of fish = 3,285'. Note found split collar on bottom of second joint pulled from well, Top of fish is a 3-1/2" eue 8rd pin. Work on winterization around draw works and run another heater line to the rig floor. MU BHA #3 - 8-1/8" hollow mill guide with 3-1/2" ID, 8-1/8" overshot with 3-1/2" grapple, 4-3/4" bumper and oil jars, (4) drill collars, 3- 1/2" PH -6 x 3-1/2" IF x -over, total length = 152.25'. RIH with BHA #3 & 3-1/2" PH -6 work string, Depth at 06:00 = 2,500'. Hilcorp Alaska, LLC ►,��r,,,,laskik,IAX Well Operations Summary Well Name JAPI Number lWell Permit Number Start Date End Date D-11 50-733-20140-00 168-073 12/13/2013 1/14/2014 Daily Operations: 12/19/13 - Thursday Continue TIH w/ 8-1/8" overshot dressed w/ 3.5" grapple, jars & drll collars on 3.5" PH -6 workstring. Rig up power swivel. Tagged top of fish at 3286' dpm, dress off fish top pumping at 2 bpm 20 psi, 50/60 rpm, 3/5k WOB, torque 1/2k, s/o and engage fish, p/u 20k over. Rig down power swivel. Pull up to 125k, 15k over and set slips & rig up E -line M/U 2": RTC cutter on E -line Test lubricator to 3,000 psi, RIH w/ cutter, log on depth cut production tbg at 10,704' ( 27' above anchor latch ), Pooh w/ E -line , unable to pass thru jars, circ at 2.5 bpm, 120 psi pump 40 bbls , able to pass thru jars, continue to Pooh ( cutter fired ), Rig down E -line. Pull up to 80k over, pipe not free, work same hit jars one time fish came free. Rig up to circ and moved equipment on deck. Circ well clean at 1-1/2 bpm 65 psi. Monitor well while blowing down circ lines, ( well static ). Pooh w/ 3.5" PH -6 work string racking in derrick. 12/20/13 - Friday Continue pooh w/ 3.5" d.p, 49 stands in derrick & 2 d.c. L/d fishing assembly. Clean and clear rig floor of the Pipe handling equipment, assist Production in changing out sheave in Boom. Pooh laying down 3.5" tbg 9.3# L-80 EUE 8rd. Back loading work boat w/ E -line equipment. Continue laying down production tbg, LAID DOWN 329 jts + CUT PIECE. Remove DSA, Break down 8-1/8" overshot assembly. Install DSA & make up BHA 5-3/4" assembly. RIH w/ 3.5" work string out of derrick. 12/21/13 - Saturday Trip in hole w/ BHA #2 ( 5-/4" overshot D/W A 3-1/2" RWH Grapple, Bumperjar, Oil jar, 4 drill collars, x/over =147.17 ) while picking up 3.5" ph -6 workstring T/ 7,821' . Secure well installing pad for roof post on rig floor. Filling hole w/ 53 bbls FIW. Continue TIH picking up 3.5" workstring t/ 10,692'. Fill hole w/ 18 bbls FIW. Rigging up power swivel and let same warm up. Check out prameters P/u wt 142k, R/T 110K, S/O WT 90K, TORQUE AT 4,500K. 5,000K, brk circ at 2.5 bpm w/ 300 psi, slack off and work over fish & latch same, at 10,716' dpm, hit jars twice at 189k, work torque into anchor latch at 6k, working fish f/ 110k to 140k, rotated same with 25 rounds, pulled out of pkr w/ 5k over pull. Circ hole clean at 3 bpm w/ 410 psi. Spotting 5 bbls nvis pill on btm. 12/22/13 -Sunday Rigging down power swive. Blow down surface lines. Pooh w/ fish. Lay out overshot ( recovered Baker PBR w/ CH anchor latch. Make up bit and Scrapper BHa = ( 6" bit, 7" 29# scrapper, double box, 91 jts 3.5" ph -6 tbg, x/o, x/o, DP x/o, 9-5/8" scrapper, DB x/o, x/o = 22.54'). RIH w/ 3.5" ph -6 TBG picking up 5 jts ph -6 to 10,745'. Rig up and reverse out at 2 bpm 450 psi for a total of 10,742' DPM, R/D lines and blow down same. Pooh w/ 3.5" ph -6 tbg. 12/23/13 - Monday Continue POOH w/ 3.5" work string w/ bit and scrappers. Break and lay out 9-5/8" csg scrappers. Continue to POOH and lay down 6" bit and 7" scrapper. Rig up to test BOPs, fill stack and lines. Test BOPS and related surface equipment to 250 psi low and 3000 psi high, test made with water held each test 5 minutes, f/ remote station, had a couple of retests due to air in lines & work & grease valves. Note: ( Mr. Bob Noble with AOGCC witness test ). Held Koomey drill. R/d Test equipment and subs. Thaw out stand pipe manifold due to froze up. Pick up and make up RTTS tools and trip in hole w/ same. 12/24/13 - Tuesday Continue RIH w/ 7" 29 RTTS tool t/ 10,205'. Unable to set packer, pick up power swivel. Set RTTS tool at 10,200 ft w/ 20k down on same, Rig up and test the 7" x 9-5/8" csg to 2,500 psi for 30 minutes on chart had 40 psi bleed down in 30 minutes, ( good test ) no pressure build up on the 13-3/8" csg during the test, bleed off test pressure and release tool. Winterize Rig, retie tarps, and wrapping stand pipe, blocking wind holes. Rigging down power swivel. Pooh w/ RTTS tool and lay out same. P/ up 5-3/4" burning shoe BHA. Trip in hole w/ Burning shoe. Hilcorp Alaska, LLC Hilcorp Alaska, LLC Well Operations Summary Well Name JAPI Number lWell Permit Number Start Date End Date D-11 50-733-20140-00 168-073 12/13/2013 1/14/2014 Daily Operations: 12/25/13- Wednesday TIH to 10,740'. Rig up Power swivel, Brk Circ, Pump Tbg volume at 2.8 bpm 420 psi, Check Parameters Torque at 7k w/ 60 RPM, pumping P/u wt 140k S/o 87k, RT wt 111. Tag top of packer at 10,749' dpm, burning on packer 2k WOB made 10". Pump increased f/ 250 psi to 800 psi at 2.5 bpm. Blow down power swivel, back flushing surface line at 5 bpm, checking pump sensors, checking for blockage. Milling on fish w/ 0 to 1 k web increasing to 2 to 4k wob pumping at 2.5 bpm 545 psi, 60 rpm 4 to 5k torque (note torque running 6800 to 7000k before adding the CFS 520 friction reducer) make a total of 26"on BOT TYPE 3 H packer, RT WT 109, PU WT 133. SO WT 111, PUMP PRESS 540 PSI 2.5 BPM, shoe not biting. Blow down lines. Rig down power swivel, flush thru surface lines Added a total of 1-1/4 drum CFS 520 to fluid system. 12/26/13 - Thursday Rigging down pack off. Pooh f/ 10,749' P/u wt 140k. Continue to pooh. Rack back drill collars and lay out Bha shoe worn 5%. Clean rig floor and inspect shoe, had discussion w/ town, Make up 6" rotary shoe. Trip in hole w/ 4-3/4" DC and 3.5 work string. Continue In hole w/ 3.5 work string. Rig up circ head and pick up power swivel. Tagged top of packer at 10,749', burning over packer at 10,749' reverse circ at 2.5 bpm 540 psi 60 rpm w/ 6k torque, w/ 10/12 wob. Circ pressure started to increase to 800 psi, shut down and bleed off to zero, flush thru surface lines, continue to burn over packer. Packer broke free pushed packer down hole w/ 0/4 WOB TO 10,834' dpm. Continue to burn over packer w/ 7k wob, w/ 6500k torque, pumping at 2.5 bpm w/ 510 psi, PU/WT 130 RTWT 114, SO/WT 96, fluid loss for 24 hrs = 78 bbls, total bbls fluid lost = 478 bbls. 12/27/13 - Friday Continue milling on packer at 10,834', pumping at 2.5 bpm 530 psi, P/u wt while rotating 112k, S/o110k, wob 8k, w/ 50/60 rpm, 5 to 6k Torq. Made 5ft down packer to 10,839'. Rig down power swivel & pack off. Blow down surface lines. Pooh had 10/12k overpull on first 2 stds f/ 10,834' to 10,714', pooh slow to top of 7" liner at 7,938'. Continue to Pooh w/ burning shoe. Pooh w/ BHA laying down Burning shoe. Making up BHA. TIH w/ workstring & overshot depth at rpt time 10,500 +/-. Fluid loss last 24 hrs 76 bbls ---- total fluid loss 554 bbls. Metal recovered f/ ditch magnets 16 lbs last 24 hrs ---- total metal recovered f/ ditch magnets 16LBS. 12/28/13 -Saturday TIH at 10,409'. Rig Generator shut down, trouble shoot same. Contacted Marsh Creek tech support. Service tech in route to platform f/ Anchorage arrived at 0400 hrs. making repairs to Generator. 12/29/13 -Sunday Fill hole w/ 50 bbls FIW, circ out gas, Continue in hole w/ BHA No 8 (Series 150 overshot w/ 4.75 normal catch spiral grapple, top sub, bumperjar, oil jar, (4) 4-3/4 drill collars, x/over = 161.63' ) to 10,827'. Rigging up pack off. Rig up Power swivel Establish circ rates and rotating weights. Circ on top of fish pump a tbg volume, pump and displace 20 bbls PFS Drill x -press LCM pill. Circ at 3 bpm 350 psi rotating at 20 rpm w/ 2900 ft lbs, work over and engage fish, and latch same, verify latch picking up to 130k, allow to meter open, with jars open pick up to 139k fish moving up hole. Rigging down power swivel, review JSA, install wiper plate, Pooh w/ fish. Pooh w/ overshot recovered (H-3 Packer @ 4.48', 4.50" LTC Millout Extension @ 5.48', 4.50" LTC X 3.50" EU X/O Sub @ 98, 3.50" EU Tubing Jt @ 31.53', 3.50" EU seating Nipple @ 1.25', 3.50" EU tubing Jt. @ 3,152', 3.50" EU Shearout sub @ .90" ) overall fish length =76.14'. Clean rig floor. Slipping and cut drill line 98'. Fluid loss last 24 hrs 35 bbls ---- total fluid loss 589 bbls. Metal recovered f/ ditch magnets 16 lbs last 24 hrs ---- total metal recovered f/ ditch magnets 16LBS. Hilcorp Alaska, LLC I l ilcorp Alaska, LLC Well Operations Summary Well Name API Number lWell Permit NumberStart Date End Date D-11 50-733-20140-00 168-073 12/13/2013 1/14/2014 Daily Operations: 12/30/13 - Monday Slip and cut drilling line 98'. Calibrate Drillers console. Rig down 13-5/8 x 7" DSA & Rig up 3.5 test equipment, fill stack and flush thru lines, Test Bops' and related surface equipment to 250 psi low and 3000 psi HIGH, held each test 5 minutes & test made with water, all test pass, preform Accumulator Time/pressure test ( all pass ) Mr. Jim Regg waived test witness on 12-29-13 at 8:15 P.M. for detail see test charts dated 12-30-13. Rig down Test equipment & blow down lines. R/u 13-5/8" DSA and clear and clean floor, make up BHA (Tapered mill w/ 6"od smooth OD, Bit sub, Drill collar, DP sub, water melon mill, Junk basket (3) DB sub, bumperjar, oil jar, (4) 4- 3/4 drill collar, slingerjar, x/over = 212.01'). Service rig. Continue picking up BHA, trip in hole with 3.5 work string tag at 10,802' set down 5k. Lay down single, Installing pack off and picking up power swivel, BROKE CIRC. LONG WAY AT 3 BPM W/750 PSI. P/U = 130K - S/O = 92K, ROT WT = 110K @ 50 RPM. WORKED THRU TIGHT SPOT F/10,798' DPM & BROKE THRU AT 10,802' TORQ UP TO 7500#. CIRC & WORK PIPE WHILE CONDITIONING FLUID W/ CFS - 520 TO REDUCE TORQ. Making connection CONT' TO WASH/MILL DOWN. Fluid loss last 24 hrs 35 bbls ---- total fluid loss 589 bbls. Metal recovered f/ ditch magnets 16 lbs last 24 hrs ---- total metal recovered f/ ditch magnets 16LBS. 12/31/13 -Tuesday CONT REAMING F/10,882', WASH F/ 10,882' TO 10,914' DPM. BACK REAM UP AND DOWN, CIRC LONG WAY @ 3 BPM 800 PSI 60 RPM TORG = 2800/3500 P/U = 110K, S/0= 107K WHILE ROTATING. TAG TIGHT SPOT @ 10,910' DPM WHEN REAM JT BACK DOWN, WORK DOWN TO 10,914' DPM TORO, = 7000 FTLBS P/U 152K 40K OVER P/U. ATTEMPTED TO MILL THRU W/ NO SUCCESS STALLED OUT @7500 FT/LBS. P/U OFF BOTTOM & CIRC 720 BBLS THE LONG WAY @ 3 BPM W/780 PSI. SHUT DOWN MONITOR WELL ( WELL STATIC). R/D POWER SWIVEL & CIRC HEAD. BLEW DOWN ALL SURFACE LINES BACK TO PITS W/ AIR. POOH W/ 6" TAPERED MILL ASSY. ( BHA =Tapered mill w/ 6"od smooth OD, Bit sub, Drill collar, DP sub, water melon mill, Junk basket (3), DB sub, bumperjar, oil jar,(4) 4-3/4 drill collar, slingerjar, x/over = 212.01' ). L/D TAPERED/STRING MILL BHA, THE 3 BOOTS BASKETS WHERE EMPTY. SERVICE RIG. CLEAR RIG FLOOR & PREP TO P/U BHA. P/U 5-3/4" WASH -OVER ASSY W/ FLAPPER & PUMP -OUT SUB BHA & TIH W/ SAME. BHA + ROTARY SHOE ( OCEAN WAVE W/ 5.75 SMOOTH OD X 5.125 SMOOTH ID, WASHPIPE EXT 5.75'W/ FLAPPER VALVE, WASHPIPE DRIVE SUB W/ DEBRIS FILTER, PUMP OUT SUB, BUMPER JAR, OIL JAR, (4) 4-3/4 DRILL COLLARS, LINGER JAR, X/ OVER SUB = 202.14'. TIH W/ 3 1/2" DP TO 10,902'. RIGGING UP PACKOFF AND PICKING UP POWER SWIVEL, BRK CIRC AND CHECKING PARAMETERS. Fluid loss last 24 hrs 0 bbls ---- total fluid loss 589 bbls. Metal recovered f/ ditch magnets 3.7lbs last 24 hrs ---- total metal recovered f/ ditch magnets 19.7 LBS. 01/01/14 - Wednesday SERVICE RIG & REVIEWED JSA'S. CONT' TO REVERSE CIRC @ 2 1/2 BPM W/580 PSI, ROT @ 60 RPM W/ 5K -7K TORQ. ATTEMPT TO WASH DOWN T/ 10,914' DPM. PIPE PLUGGED & PRESSURE UP T/ 780 PSI. ATTEMPT TO UN -PLUG PIPE W/ NO SUCCESS. PUMP THRU ALL SURFACE LINES/EQUIP @ 5 BPM 1100 PSI TO VERIFY PLUG WAS IN D.P. R/D POWER SWIVEL & N/D CIRC HEAD. BLEW DOWN SURFACE LINES W/ AIR BACK TO TANKS. ATTEMPT TO POOH W/ WASH PIPE ASSY. PIPE PULLING WET. CONT' TO POOH W/ 6" WP ASSY. T/ 2,148' DPM. SERVICE RIG & REVIEWED JSA'S. CONT' TO POOH W/ WP ASSY. POOH & L/D 6" OCEAN WAVE SHOE, WASH PIPE, W/ FLAPPER BHA. LAST 120' OF BHA WAS PACKED SOLID W/ SAND/GRAVEL. CLEAN RIG FLOOR & PIPE RACK. CHANGE SHAKER SCREENS TO 120'S, DRAINED DIRTY FLUID F/ TANKS & FILLED WITH CLEAN FIW. P/U 3-1/2" MULE SHOE & TIH W/SAME TO 9,440' DPM (T.O.L.). R/U TO REV. CIRC & REVERSED OUT UNTIL HOLE CLEAN. (TOTAL PUMPED = @ 4 BPM W/ 1200 PSI.) CONT' TO TIH W/ MULE SHOE - NO GAIN, NO LOSS. Fluid loss last 24 hrs 0 bbls ---- total fluid loss 589 bbls. Metal recovered f/ ditch magnets o lbs last 24 hrs ---- total metal recovered f/ ditch magnets 19.7 LBS. Hilcorp Alaska, LLC IIiI4orI)Alit xka,LIA: Well Operations Summary Well Name API Number lWell Permit Number IStart Date I End Date D-11 50-733-20140-00 168-073 12/13/2013 1/14/2014 Daily Operations: 01/02/14 - Thursday SERVICE RIG. CONT TIH W/3.5" DP & MULE SHOE F/ 10,050'DPM TO 10,176'DPM. R/U & REV CIRC 1 TBG VOL @ 3 BPM 650 PSI PUMPED 74 BBL. ATEMPT TO R/D CIRC HOSE - WELL U -TUBING. CONT CIRC @ 3 BPM 650 PSI PUMPED 60 BBL. CONT RIH F/ 10,176'DPM TO 10,553'DPM, REV CIRC @ 4 BPM 1020 PSI PUMPED 83 BBL. CONT' TIH F/ 10,176'- 10,553' DPM. R/U PACK OFF HEAD & POWER SWIVEL. REV CIRC @3 BBL 600 PSI RPM 15 TORO, 2K S/0 TO 10,914' DPM 2K DOWN PSI INCREASED TO 870 PSI. P/U & CIRC 1 TBG VOL, S/0 TO 10,916' DPM BPM SET 3K DOWN P/U TO 10,913'DPM AND REV CIRC @ 4 BBL 570 PSI. PUMPED TOTAL 160 BPM. SECURE WELL. DUMP SURFACE VOL & CLEAN RIG TANKS. DISP WELL W/FIW LONG WAY CIRC @3 BPM 350 PSI 10,916' DPM PUMPING RETURNS TO PROD. PUMPED A TOTAL OF 1355 BBLS. OFFLOADED & SPOTTED WIRE -LINE EQUIP. L/D SINGLE JNT OF D.P. & R/D POWER SWIVEL. GATHER CREW FOR JSA ON HANGING WIRE -LINE SHEAVE AT CROWN, & P/U PACK -OFF. P/U PUP JNTS, SIDE - ENTRY SUB, TIW, & PACK -OFF ASSY. RIH TO TARGET DEPTH OF 10,914' DPM. R/U & HANG WIRE -LINE SHEAVE IN CROWN. P/U 1- 11/16" CAMERA AS PER W.L. RIH W/ 1-11/16" CAMERA ON WIRE -LINE AS PER W.L. PROCEDURES. PERFORMED GENERAL MAINT ON MUD PUMP, DRAWWORKS, & OTHER MISC RIG EQUIP. RIH TO 6,000' WLM, LOST VISABILITY W/ CAMERA. L/U & PUMPED CLEAN FIW DWN TBG TO INCREASE VIS. RIH W/ W.L. T/ 10,914' WLM PUMP FIW DWN TBG TO INCREASE VISABILITY AS NEEDED. 01/03/14 - Friday CONT' TO RIH W/ E -LINE 1-11/16" CAMERA WHILE CIRC @ 1 BPM 5 PSI T/ 10,936' WLM. LATCHED ONTO DP & P/U TO 10,912' DPM. CONT' LOGGING DOWN HOLE W/ E -LINE CAMERA WHILE CIRC @ 1 BPM W/ 5 PSI. WORKED PIPE BACK DOWN TO 10,914' DPM. POOH W/ E -LINE unable to see w/ btm camera. R/D E -LINE PACK -OFF & REMOVED BOTTOM CAMERA. MADE UP PACK -OFF & RIH W/ E -LINE SIDE VIEW CAMERA. LATCHED ONTODP & P/U TO 10,908' DPM. LOGGED/VIDEO DOWN TO 10,934WLM. S/0 DP TO 10,914' DPM & POOH W/ SIDE VIEW E -LINE CAMERA. RE -INSTALLED BOTTOM VIEW CAMERA & PREP TO RIH W/ SAME. RIH W/ BOTTOM/SIDE VIEW E -LINE CAMERA. AT 10,000' WLM BEGAN CIRC @ 1 BPM W/ 5 PSI TO INCREASE VISABILITY. CONT' TO RIH W/ E -LINE 1-11/16" CAMERA WHILE CIRC @ 1 BPM 5 PSI T/ 10,936' WLM. WORK DP TO CORALATE DEPTH W/ E -LINE. POOH W/ E -LINE CAMERA, ASST. PRIORTY WL R/D E -LINE TOOLS, & EQUIP. PREP TO POOH W/ DP, L/D PUP JNTS, & W.L. ENTRY ASSY. R/D CIRCULATING HEAD & L/D (1) JNT OF 3-1/2" DP T/ GET ON EVEN STNDS. POOH W/ 3-1/2" DP/ MULE SHOE. BREAK DOWN FISHING TOOLS. PERFORMED GENERAL HOUSEKEEPING/MAINT AROUND RIG. INVENTORY MISC SUBS. PREP FOR WIRE-LINERUN WHILE WAITING ON CSG CALIPER LOGGING TOOL TO ARRIVE ON BOAT. 01/04/14 - Saturday P/u and Brk down fishing tools. Rig up E -line & RIH w./ SRO 40 finger, Sondex Caliper tool to 10,805'. Logging out of hole at 50 fpm f/ 10,805' to surface. Rig down E -line. This W/ 3.5 PH -6 work string until string is 35k ( 39 stds ). P/u 9-5/8" RTTS & Strom valve and continue TIH setting the RTTS & STROM valve at 166' testing same to 1600 psi held for 20 minutes, bleed off same. Drained BOP's, bleed down Koomey lines, n/d choke & kill lines, broke bolts on tbg head, hook up rig up lines to blk. P/u BOP's/ riser & remove 13- 5/8" 3k x 11" 5k seaboard tbg spool, removing old bolts, & cleaning up tbg spool. 01/05/14 - Sunday ASSIST SERVICE TECH SWAP OUT 13-5/8" X 11" KELCO TBG HEAD. ASST TECH - VOID TEST TBG HEAD. PRESSURED UP TO 3000 PSI & HELD FOR 15 MINS. N/U BOPS, RISER, & CHOKE/KILL LINES. CLEAN/ P/U IN WELL BAY. INSTALLED FLOOR BEAMS/ PLATE. SECURED BOP STACK. RE -INSTALLED POLLUTION PANS AROUND RISER. CLEAN & CLEAR RIG FLOOR & BOP AREA. R/U STACK & ALL SURFACE EQUIP. P/U 3-1/2" TEST ASSY. RIH & SET TEST PLUG. R/U TO TEST BOP'S. TEST 13-5/8" BOPS & RELATED SURFACE EQUIPMENT AS PER AOGCC AND HILCORP SPECS 250 PSI LOW/3000 PSI HIGH ON CHART DATED 1-5-14. SEE CHART AND DETAIL SHEET. ATTEMPTED TO TEST 2-7/8" X 5" VBR'S, & HYDRIL. BOTH LEAKING. MADE SEVERAL ATTEMPTS TO TEST NO LUCK. R/U & TESTED KELLY VALVE ON POWER SWIVEL to 250 LOW 3000 PSI HIGH AS PER AOGCC SPECS ON CHART. SEE DETAIL SHEET. PULLED TEST PLUG & R/U TO TEST BLIND RAMS & TBG HEAD. TO 2500 PSI AS PER AOGCC & HILCORP SPECS ON CHART. DRAINED STACK TO VISUALLY INSPECT RAMS / HYDRIL. OPENED BONNENTS & VERIFIED DAMAGE PULLED RAMS OUT & N/D RISER SPOOL. BROKE HYDRIL CAP & PULLING HYDRIL RUBBER. WITNESS OF TEST WAIVED BY JIM REGG, AOGCC. HHilcorp Alaska, LLC ►�,►�,,,,,:011,11,41. LIX Well Operations Summary Well Name API Number lWell Permit Number Start Date End Date D-11 50-733-20140-00 168-073 1 12/13/2013 1/14/2014 Daily Operations: 01/06/14 - Monday CONT' TO N/D RISER SPOOL F/ TOP OF HYDRIL. PULLED CAP OFF HYDRIL. R/R HYDRIL RUBBER & 2-7/8" X 5" VBR'S. RE-INSTALLED HYDRIL CAP & TIGHTENED CAP & BONNENTS. FUNCTION TESTED SAME. P/U 2-7/8" TEST ASSY. F/U STACK W/ FIW. R/U & PREP TO TEST BOPS. TEST HYDRIL & VBR'S W/ 2-7/8" DP 250 LOW / 3000 HIGH ON CHART AS PER AOGCC & HILCORP SPECS. SEE DETAILED SHEET. WITNESS OF TEST WAIVED BY JIM REGG, AOGCC. L/D 2-7/8" TEST ASSY & P/U 3-1/2" TEST ASSY. TESTED SAME ON CHART AS PER AOGCC & HILCORPD SPECS 250 LOW / 3000 HIGH. (TESTED HYDRIL & VBR'S). R/D TEST ASSY. INSTALLED POLLUTION PANS AROUND BOP'S, & R/U TARPS & HEATERS AROUND SAME. P/U SSC R/R TOOL & RIH W/ SAME SCREWED INT STORM PACKER. M/U TIW VALVE ON DP. P/U TO 40K (5K OVER) TO UN-SET PACKER. L/U &CONT' TO CIRC TO FILL HOLE & GET AIR OUT OF SYSTEM. PUMPED 72 BBLS TOTAL @ 5 BPM W/ 0 PSI. POOH & L/D STOR PACKER. POOH W-3 -1/2" DP, N/U ADAPTER FLANGE, SWAP HANDLING EQUIP. CLEAR MISC SUBS/EQUIP FROM RIG FLOOR. P/U (5) SPF TCP GUNS & TIH W/ SAME. (16) GUNS TOTAL (3) BLANKS, (7) PARTIALS, (5) FULLY LOADED, (1) PARTIABOTTOM GUN, P/U RADIOACTIVE MARKER SUB & TIH W/-3 1/2" DP WHILE DRIFTING OUT OF DERRICK. Fluid loss last 24 hrs 72 bbls ---- total fluid loss 661 bbls. 01/07/14 - Tuesday SERVICE RIG & HELD JSA. CONT' TIH W/ TCP GUNS T/ 10,770' DPM WHILE DRIFTING PIPE OUT OF DERRICK. R/U E-LINE EQUIP. P/U 1- 11/16" GAMMARAY & WEIGHT BAR & RIH W/SAME TO 10,250' WLM & LOG UP TO 9,950' WLM. LOG F/ 10,760'-T/9,950' WLM. CORALATE E-LINE / GUNS. GUNS ON DEPTH RA TAG @ 10,229' ELM. POOH W/ E-LINE & R/SAME. L/D SINGLE & P/U 10' PUP. SPACED OUT & R/U TIW'S, SIDE-ENTRY SUB, & KELLY HOSE. CONT' R/U PERF / PUMPING ASSY ON TOP OF WORKSTRING. DROPPED BAR & FIRED GUNS. TOP SHOT @ 10,406' DPM - BOTTOM SHOT @ 10,730' DPM. FIW, L/U & REV CIRC AT 2-1/2 BPM W/ 195 PSI. PUMPED 185 BBLS TO CIRC OUT GUN GAS/DEBRIS (LOST 18 BBLS). MONITORED WELL FOR GAIN/LOSSES. (WELL STATIC), L/D SPACE OUT & PUMPING ASSY. PREP TO POOH. POOH W/ 3-1/2" DP & TCP GUN ASSY. POOH & L/D TCP GUN ASSY. Fluid loss last 24 hrs 23 bbls ---- total fluid loss 684 bbls. 01/08/14- Wednesday Cont POOH with TCP assy. Held JSA on breaking out and laying down TCP assy. B/0 & L/O TCP assy. Clean rig floor of TCP handing tools & wash down same. TIH with 3-1/2" mule shoe and 3-1/2" PH-6 work string to 10,500'. Lay out prod tbg on pipe rack and strap same. POOH laying out 3-1/2" PH-6 work string stacking same on top of production tbg in bundles of 20 jts. Clean rig floor. Held JSA for rigging up e-line & rig up same and back load work string to work boat. 01/09/14 - Thursday Held JSA with crew on rigging up e-line & finished rigging up same. RIH to 10,250' with 5.96" OD gauge ring on junk basket. POOH with same. PU & MU Model D packer assy. RIH with same on e-line to 10,250' log & correlate same on depth putting top of packer @ 10,210'. Attempted to fire setting tool w/o success. POOH with packer assy and e-line. L/O Packer assy, inspect e-line and found gamma ray shorted out. Removed gamma ray. P/U and M/U Model D packer assy on e-line & RIH to 10,255', logged guns on depth with collar log attempted to fire setting tool w/o success. POOH to surface with e-line and packer assy. B/0 & L/0 Model D packer assy. R/D e-line equipment. Spot e-line, re-head wire, and connect same to Model D packer assy. Total fluid loss to well = 67 bbls in last 24 hrs, total fluid loss to well = 744 bbls. 01/10/14 - Friday Held JSA. M/U 7" Mod packer assy. to e-line. RIH with same to 10,250'. PU and correlate packer on depth and set at 10,210'. POOH and R/D e-line. Held JSA on P/U & M/U & RIH with production string. PU/ and M/U 4" seal assy, RIH with seals, picking up & rabbiting 2-7/8" EU 8rd tbg & GLM's from pipe rack. Depth at 06:00= 9,056'. Total fluid loss in last 24 hrs = 72 bbls. Hilcorp Alaska, LLC Ilile rpAlaska,LLC Well Operations Summary Well Name API Number lWell Permit Number Start Date End Date D-11 50-733-20140-00 168-073 12/13/2013 1/14/2014 Daily Operations:` 01/11/14 -Saturday Continue RIH with 2-7/8" production tbg and GLM's picking up tbg and rabbiting same from pipe rack with 2.39" od rabbit. PU & MU SCSSSV, connected control line to same functioned valve also tested connection to 5000 psi for 15 min. Continue RIH with 2-7/8" production tbg and SCSSSV, spaced out and landed hanger with 10k wt down on packer seal assy at 10,210'. Perform rig maintenance and house keeping. R/U slick line and attempted to RIH and set PX plug in 2.313" X nipple at 10,201' w/o success. Plug hung in tbg at 2,220' wlm. RIH with 2.290" od gauge ring and hung up at 2,220' wlm. POOH and RIH with 2.250" gauge ring and hung again @ 2,220' wlm. Gauge rings had marks on OD indicating crushed tbg. RD wire line and prepare to POOH with production string. Pull hanger to surface, B/O & L/O same continue POOH with 2-7/8" production string standing same back in derrick. Found joint above first GLM crushed below collar connection at 2,229' DPM. Total fluid lost to formation in past 24 hrs = 32 bbls 01/12/14 -Sunday SERVICE RIG & RIG UP S -LINE. M/U LUBRICATOR. M/U 2.29" GAUGE RING ON S -LINE RIH W / SAME. TAG @ 2,932' SLM. UNABLE TO GET DOWN. POOH W / S-LNE. M/U 2.25" GAUGE RING & RIH TAG @ 4,849' SLIM. POOH W / S -LINE AND R/D SAME. POOH W/2-7/8" PROD TBG INSPECTING EACH JT FOR DAMAGE. LAYDOWN DAMAGED JT @ 2,932'. R/U S -LINE. M/U 2.29" GAUGE RING AND RIH W/SAME 5,080' SLM. POOH & R/D S -LINE. POOH W/ 2-7/8" PROD TBG INSPECTING & L/O DAMAGE JTS. INSPECT PACKER SEAL ASSY & RIH W / SAME. TOTAL OF 6 BAD JTS. TIH W/ 2-7/8" PROD TBG & DRIFTING OUT OF DERRICK. INSTALLING GAS LIFT MANDRILS AT CORRECT DEPTH INSPECTED EACH CONNECTION AFTER TIGHTENING W/ HYDRALIC TONGS. FLUID LOST TO FOPRMATION IN LAST 24 HRS = 37 BBLS. 01/13/14 - Monday Continued in hole with 2-7/8" 8 rd tbg, GLM's and SCSSSV, spaced out same and landed packer seals with 10k down on packer. PU 2' to get hanger out of well head. RU slick line, made 2.29" od gauge ring run to 10,230'. POOH with same, ran and sat 2.313" PX plug and prong in x -nipple @ 10,175'. R/U & test tbg to 3000 psi and casing to 2500 psi for 15 min each ( test ok ). RIH with slick line and retrieve prong and PX plug @ 10,175'. R/D slick line. Slack off land hanger, run in hold down pins. Set BPV, terminate SCSSSV, Bled off accumulator, disconnected Koomey lines, N/D BOP's, riser spools, pollution pans and flow lines. PU production tree and prepare to land same. 01/14/14 -Tuesday N/U tree, tested void to 5000 psi f/ 15 mins, body test tree to 5000 psi for 15 mins on chart (ok). R/D power tongs, unwire drillers shack, remove hyd hoses from same. Unbolt shack and move to pipe rack. Move compressor building from skid beams to pipe rack. R/U scaffolding & secure same on and around drillers side of derrick. Remove tong counter weights roll up and cover wiring and hoses with fire blankets. R/U anti -fall devices and hand rail over and around elevated work platform. Assist welders in cutting out and removing diagonal beam on drillers side of derrick while continuing move and prepare other related equipment for rig move. Schwartz, Guy L (DOA) From: Dan Marlowe <dmarlowe@hilcorp.com> Sent: Monday, January 06, 2014 6:02 AM To: Schwartz, Guy L (DOA) Cc: Ted Kramer; Juanita Lovett Subject: RE: D-11 Sundry 313-464, PTD 168-073 Attachments: D-11 proposed gaslift wellhead drawing.docx As requested From: Schwartz, Guy L (DOA) [ ,ailto:guy.schwartz@alaska.gov] Sent: Friday, January 03, 2014 1:33 PM To: Dan Marlowe Cc: Ted Kramer; Juanita Lovett Subject: RE: D-11 Sundry 313-464, PTD 168-073 Dan, Your proposal (to run a GL completion) is approved if casing issues don't allow you clean out the well past 10914' md. Please forward the new tubing head/tree diagram for the gaslift completion as soon as you can. Guy Schwartz Senior Petroleum Engineer AOGCC 907-301-4533 cell 907-793-1226 office From: Dan Marlowe [ `hilcorp.com] Sent: Friday, January 03, 2014 1:19 PM To: Schwartz, Guy L (DOA) Cc: Ted Kramer; Juanita Lovett 5E, Subject: D-11 Sundry 313-464, PTD 168-073 Guy We have ran into some casing issues at —10,914' that may prevent us from cleaning out this well past the top of the hemlock. We are in the middle of running a camera to determine a plan forward. Given that it is Friday afternoon though I wanted to discuss it with you prior to the weekend. Here are a couple versions of gas -lift completions that we may decide to run if the esp completion is a no-go. One is a 2-7/8. The other is a 3-1/2 We have tested the casing at 10,200' to 2500 psi and charted Procedurally the plan forward would be • POOH with work string —500' and pick up storm packer • RIH to —350' and set storm packer. Test to 1500 psig • Release from storm packer and change out tubing head — pressure test to 2500 psig and chart • Retest all connections of BOP stack that were broken back to • Pull storm packer • PLI and run TCP guns and perforate G -zone Run Gas -lift completion Dan Marlowe Hilcorp Alaska, LLC Operations Engineer Office 907-283-1329 Cell 907-398-9904 Fax 907-283-1315 Email DMarloweCdOilcorp.com Hilcorp A Company Built on Energy I 'H Hilen? Almka,1JA: Dolly Varden D-11 133/8X95/8X27/8 BHTA, Bowen, 3 1/8 5M X 2.5 Bowen quick union I Valve, Swab, WKM-M, ©� 3 1/8 5M FE, HWO, DD trim 0 �p4 Valve, Wing, WKM-M, 2 1/16 5M FE, HWO, DD trim % Valve, Master, WKM-M 3 1/8 5M FE, HWO Valve, Master, WKI 3 1/8 5M FE, HWO, [ X. Contrc Tubing head, S-8, 13 5/8 3M x 11 5M, w/ 2- 2 1/16 5M SSO, w/ BG bottom w/ 1- 2 1/16 5M WKM-M valves Casing head, CIW-WF, 13 5/8 3M X 13 3/8 casing thread bottom, w/ 2- 2 1/16 5M EFO Dolly Varden Platform D-11 Proposed Gaslift 01/3/2014 Tubing hanger, SME -CL, 11 X 3 % EUE lift and susp, w/ 3" Type H BPV profile, 2- 3/8 CCL, Alloy material Valve, Wing, WKM-M, 3 1/8 5M FE, w/ 15" OMNI 7 operator, DD trim Ive, CIW-F, 2 1/16 5M FE, HWO, AA trim w w\ OFV7 s, THE STATE Alaska Oil and Gas °ALASKA. � �S � T ��1� Commission GOVERNOR SEAN PARNELL 333 West Seventh Avenue rh �, Anchorage, Alaska 99501-3572 ALA9� Main: 907.279.1433 Fax: 907.276.7542 VANED 1\10 _ 3 2-Tj i 3 Dan Marlowe Operations Engineer Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 100 1 Anchorage, AK 99503 Re: McArthur River Field, Hemlock Oil Pool, Trading Bay Unit D-11 Sundry Number: 313-464 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. This sundry authorizes Hilcorp to recomplete Trading Bay Unit D-11 (PTD 168-073) to a packerless ESP producer. As such, all production from the Middle Kenai G and Hemlock formations will be commingled. Conservation Order 234A, Rule 3 requires that commingled production be allocated using production logging or some other means approved by the Commission. Hilcorp has applied for a blanket waiver to allow ESP wells to be produced without production logs. Until this waiver is granted the well may not be produced and Hilcorp takes all risk in the case that this waiver is not granted. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Cathy P. oerster Chair, ommissioner DATED this?day of October, 2013. Encl. • • RECEIVED STATE OF ALASKA AUG 2 7 2013 I ALASKA OIL AND GAS CONSERVATION COMMISSION s ii o) I 1 t APPLICATION FOR SUNDRY APPROVALS AOSCC 20 AAC 25.280 1.Type of Request: Abandon❑ Plug for Redrill❑ Perforate New Pod M ' Repair Well❑ Change Approved Program❑ Suspend❑ Plug Perforations❑ Perforate O a Pull Tubing M • e sP Time Extension❑ Operations Shutdown Cl Re-enter Susp.Well❑ Stimulate❑ Alter Casing❑ Other.Clean out&Complete M • 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number. Hilcorp Alaska,LLC Exploratory El Development GI, 168-073 . 3.Address: Stratigraphic ❑ Service El 6.API Number. 3800 Centerpoint Drive,Anchorage AK,99503 50-733-20140-00 ' 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 G Trading Bay Unit D-11• 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL017594- 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): 11,514 9,905 10,957 9,478 N/A 10,957(Fish) Casing Length Size MD TVD Burst Collapse Structural Conductor Surface 2,511' 13-3/8" 2,511' 2,349' 3,090psi 1,540psi Intermediate Production 9,691' 9-5/8" 9,691' 8,455' 5,750psi 3,090psi Liner 2,074' 7" 11,514' 9,905' 8,160psi 7,020psi Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See Attached Schematic See Attached Schematic 3-1/2" 9.3#/L-80 10,821' Packers and SSSV Type: Packers and SSSV MD(ft)and ND(ft): Baker 3H Perm Packer and TR SCSSV Type FMX 10,745'(MD)/9,314'(TVD)and 370'(MD)/370(TVD) 12.Attachments: Description Summary of Proposal El 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch G Exploratory ❑ Stratigraphic❑ Development!- Service ❑ 14.Estimated Date for 15.Well Status after proposed work: 9/21/2013 Commencing Operations: Oil 0• Gas ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: N/A WINJ ❑ GINJ ❑ WAG ❑ Abandoned ❑ Commission Representative: N/A GSTOR ❑ SPLUG ❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Dan Marlowe Email dmarlowe @hilcorp.com Printed Name Dan Marlowe Title Operations Engineer Signature one (907)283-1329 Date 8/26/2013 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Plug Integrity ❑ BOP Test 12/ Mechanical Integrity Test ❑ Location Clearance ❑ p Other: -t c7 � .DP c�1 Br ME OCT 1 0 20 ' /V O F�b 41�` --f e-S I" r wi-r / /� Y�/ // 1 I0 (.✓J p—hcC • �+.pp rO,cX e �{ Go+�rrL i r.J�c;L� (.�a-�iN c r. l rD�f rti v�'i Qy. �'( U Spacing Exception Required? Yes ❑ No Of Subsequent Form Required: 0_Loci 0:67 p;iite.4_44„, THERO BY /0 I Z -/3 Approved by: COMMISSIONER THE COMMISSION Date: S•3 /3 pp a n tloG N A pp Submit Form and Form 10-403(Revised 10/2072 A rove T�1[`a �vf! I 1'�r1Onfhs from the date of a rov 1. Attachments in Duplicate `6`�� Well Work Prognosis Well: D-11 Hilcorp Alaska,LLC Date: 08/26/2013 Well Name: Trading Bay Unit D-11 API Number: 50-733-20140-00 Current Status: SI Producer(Gas Lift) Leg: Leg#A-2 (NW corner) Estimated Start Date: September 06,2013 Rig: HAK#1 Reg.Approval Req'd? 403 Date Reg.Approval Rec'vd: Regulatory Contact: Juanita Lovett _ Permit to Drill Number: 168-073 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: ^'3,400 psi @ 9,186'TVD/11,100 MD .37 psi/ft.,(7.0 ppg)at mid-perf of all perfs Max.Expct'd BHP: ^'3,400 psi @ 9,186'TVD/11,100'MD .37 psi/ft.,(7.0 ppg)No new zones Max.Possible SP: 2581 psi Using 0.10 psi/ft back to surface Brief Well Summary This well last produced in April 2007 and was making 325 bpd gross, 85%water cut, 2.6 mmscfd lift gas.This workover consists of removing the current completion, removing the Baker model 3H permanent packer at 9,686'cleaning out the well bore,and cleaning down to 11,425'. New perforations will be shot with deep,dynamic underbalance guns opening the G,and Hemlock formations. The well will then be completed with an ESP ran on 3-1/2"tubing as the means of artificial lift.Well is expected to make 2000-4000 bfpd at 10-15%oil cut. Notes Regarding Current Wellbore Condition • November 2008 impression block run indicates parted tubing at 3,238' _ • Last known tag July 1999 at 10,957' (wireline fish) • Bad spot in casing 10,898' BLM that will need dressed up at a minimum Procedure: 1. Skid rig and.RUHAK Rig 1 over D-11 well slot. _ 2. Plumb filtered inlet water(FIW) lines to circulate down the annulus and up the tubing, or vice versa, through the tree, make sure there is no gas in the tubing or annulus. 3. Notify AOGCC 24 hrs before pending BOPE test. Set BPV, ND tree, NU BOPE. Test all BOP equipment per AOGCC guidelines to 250 psi LOW and 3,000 psi HIGH. 4. Load well with FIW. Pull on tubing. It is expected to come free at 3238'. POOH, LD tubing. Inspect parted tubing to determine fishing plan. Recover tubing, GLM5, and seal/anchor assembly. 5. Mill and pluck packer with a one-trip packer retrieving tool as there is a millout extension. If packer is pushed down it is likely to get wedged in bad spot in casing at 10855' or get stuck across perfs, making retrieval difficult. 6. Gauge and dress bad spot in casing at 10,855' as needed 7. Clean out fill and fish to PBD of 11,425'for 35' of rathole. Circulate and clean hole with clean FIW. • • Well Work Prognosis Well: D-11 Hilcorp Alaska,LLC Date: 08/26/2013 8. Make bit and scraper run. PU retrievable test packer and RIH to 10,100'. Test backside to 1500 psi to confirm casing integrity per sundry requirements. (j D,rwH-- 9. Release packer. Circulate hole clean with clean,fresh FIW. POOH. 10. MU large TCP guns and perforate G-Zone and Hemlock per Perf Program with deep penetrating, dynamically underbalanced guns. Fill well one time to confirm well is static. POOH. Do not pump salt and/or polymer pills or run trip tank pump over top of well. ZONE TOP(MD) BTM(MD) TOP(ND) BTM(ND) AMT G-1 ±10,291 ±10,305 ±8,950 ±8,962 12 G-2 ±10,327 ±10,359 ±8,980 ±9,006 26 G-3 ±10,406 ±10,440 ±9,044 ±9,071 27 G-4 ±10,458 ±10,487 ±9,086 ±9,109 23 G-4 ±10,498 ±10,566 ±9,118 ±9,173 55 G-5 ±10,644 ±10,671 ±9,235 ±9,256 21 G-5 ±10,686 ±10,730 ±9,268 ±9,302 34 HB-3 ±10,897 ±11,027 ±9,432 ±9,531 99 HB-4 ±11,027 ±11,149 ±9,531 ±9,624 93 HB-5 ±11,194 ±11,300 ±9,658 ±9,739 106' HB-6 ±11,330 ±11,390 ±9,763 ±9,809 46 11. Losses are likely to occur following the re-perforation event until the well finds its stable point again. There is no need to circulate the hole,following re-perforation. After detonation, monitor well by shooting a fluid level and/or noting any flow. Once the well is determined to be static, POOH. 12. POOH with guns. LD same. Confirm that all charges fired. 13. MU motor and pump and cable spooling equipment and run ESP and 3-1/2" L-80 RTS-8 9.3#tubing. Place bottom of pump at approximately 10,100' MD (8795' ND) which is within 200' of the top G-zone perf. Land hanger and secure all penetrations. ND BOP, install new tree. Turn well over to Production Supervision for final hookup of ESP. Place well on production. 14. Well is expected to make between 2000 and 4000 bfpd at about 90%water cut. 15. Gradually bring ESP up to full speed. Place well in test. Test for several days to measure cut and fluid rate and monitor the water cut as the well cleans up. Gradually bring the speed of pump up until the bottom-hole flowing pressure is no less than 1000 psi, but do not allow fluid rate to exceed 4000 bfpd of gross fluid. Attachments: Alb �l -r o w 1. As-built Well Schematic 2. Proposed Well Schematic 3. BOP Drawing 4. Current Wellhead Diagram 5. New Wellhead Diagram 1 li • • As C McArthur River ed: Field3/16/89,TBU SCHEMATIC Well # D-11 llilcorp Alaska,LIT, RKB to TBG Head = 106.90' CASING AND TUBING DETAIL Tree connection: 4-1/6" 5,000# SIZE WT GRADE CONN ID TOP BTM. C 13-3/8" 61.0 K-55 Butt.LT&C 12.515 Surf 2,511' m 0 J I 1 9-5/8" 40,43.5,47 N-80&rs-95 8rd LT&C 8.681 Surf 9,691' t 7" 29 N-80 8rd LT&C 6.184 7938' 11,514' Tubing: 3-1/2" 9.3 L-80 EUE 8rd 2.992 0' 10,821' 2 1 JEWELRY DETAIL N , Depth ID Item 11/14/08: 3 0 Cameron'F'Tubing hanger,4-1/2"ASL Top X Btm. Parted tbg 1 370' 2.813 3-1/2"Otis Series 10 TR SCSSV Type FMX at 3240' ' 4 2 2,477' 2.867 3-1/2"Camco MMG II Mandrel#1 w/AB Mod.EUE 8rd couplings w/ GLESCO R-20 1.5"w/16/64"Port w/RK Latch 5 3 4,646' 2.867 3-1/2"Camco MMG II Mandrel#2 w/AB Mod.EUE 8rd couplings w/ GLESCO R-20 1.5"w/16/64"Port w/RK Latch 4 6,214' 2.867 3-1/2"Camco MMG II Mandrel#3 w/AB Mod.EUE 8rd couplings w/ 6 GLESCO R-20 1.5"w/16/64"Port w/RK Latch 5 7,341' 2.867 3-1/2"Camco MMG II Mandrel#4 w/AB Mod.EUE 8rd couplings w/ GLESCO R-20 1.5"w/20/64"Port w/RK Latch — 7 6 7,978' 2.867 3-1/2"Camco MMG II Mandrel#5 w/AB Mod.EUE 8rd couplings w/ L O , GLESCO R-20 1.5"w/16/64"Port w/RK Latch. M T Has MERLA trigger behind GLV,cannot be retrieved. 8 7 8,561' 2.867 3-1/2"Camco MMG II Mandrel#6 w/AB Mod.EUE 8rd couplings w/ GLESCO R-20 1.5"w/24/64"Port w/RK Latch 9 8 9,144' 2.867 3-1/2"Camco MMG II Mandrel#7 w/AB Mod.EUE 8rd couplings w/ GLESCO R-20 1.5"w/28/64"Port w/RK Latch 101 r 9 9,752' 2.867 3-1/2"Camco MMG II Mandrel#8 w/AB Mod.EUE 8rd couplings w/ 12 7y S GLESCO R-20 1.5"w/28/64"Port w/RK Latch 10 10,359' 2.867 3-1/2"Camco MMG II Mandrel#9 w/AB Mod.EUE 8rd couplings w/ i 13 GLESCO R-20 1.5"w/28/64"Orifice w/RK Latch 14 11 10,731' Baker Locator Seal Assy,12'long. – –Tight 10,731' Baker PBR w/'CH'Anchor Latch. Spot @ 15 12 10,745' 7"29#Baker 3H Perm.Pkr.w/Millout ext.(4-1/2"EUE 8rd Pin X Pin) 10855' C 13 10,756' 2.992 4-1/2"X 3-1/2"XO(8rd Box X EUE Pin) ' ) 14 10,788' 2.75 Otis"XN"Nipple,2.813 15 10,821' 2.992 Baker Shearout sub B-1,3 Fish Tagged @ 0 21'of Wireline tools, 12/2/92 @ 11,185'WLM 43'of wireline tool,7/10/1999 @ 10957'BLM A_ B-4 PERFORATION DATA e{ ZONE TOP BTM AMT SPF DATE B-5 B-1,3 10,902 10,985 83' 6 3/89 f' B-6 B-4 10,998' 11,154' 156' 6 3/89 B-5 11,220 11,250 30' 6 3/89 11,194 11,300 106' 2 10/75 j \ B-6 11,320 11,390 70' 2 10/75 PBTD = 11,425'TD = 11,514' MAX HOLE ANGLE = 42°, KOP @ 400' Updated by: JLL 06/14/13 • • McArthur River Field,TBU , H PROPOSED Well # D-11 As Completed: Future Hilcorp Alaska,LLC RKB to TBG Head = 106.90' CASING AND TUBING DETAIL Tree connection: 4-1/6" 5,000# SIZE WT GRADE CONN ID TOP BTM. C 13-3/8" 61 K-55 Butt.LT&C 12.515 Surf 2,511' m 9-5/8" 40 N-80 Buttress 8.835 Surf 5,238' t 9-5/8" 43.5 N-80 Buttress 8.755 5,238' 6,760' 9-5/8" 47 N-80 Buttress 8.681 6,760' 8,215' 9-5/8" 47 RS-95 LT&C 8.681 8,215' 9,691' 7" 29 N-80 8rd LT&C 6.184 9,440' 11,514' Tubing: 3-1/2" 9.3 L-80 RTS 8rd 2.992 Surf ±10,080' JEWELRY DETAIL N Depth Item Cameron'F'Tubing hanger,4-1/2"ASL 0 Top X Btm. 1 ±10,080' Top of pump 2 ±10,157' Pump Intake 3 ±10,173' Top of Motor 4 ±10,236' Phoenix PIT Gauge C , 5 ±10,240' Bottom of GLM Anode M T Mt 2 Fish Tagged @ 3 ALL FISH TO BE REMOVED DURING WORKOVER 4 21'of Wireline tools,12/2/92 @ 11,185'WLM 5 43'of wireline tool,7/10/1999 @ 10,957'BLM G-1 G-2 PERFORATION DETAILS G-3 Tight ZONE TOP(MD) BTM(MD) TOP BTM AMT SPF DATE Present spot @ G-4 10855' ' (TVD) (TVD) Condition y/) G-5 G-1 ±10,291 ±10,305 ±8,950 ±8,962 12 Future HK-3 G-2 ±10,327 ±10,360 ±8,980 ±9,007 26 Future B-1,3 G-3 ±10,406 ±10,443 ±9,044 ±9,073 27 Future G-4 ±10,458 ±10,487 ±9,086 ±9,109 23 Future G-4 ±10,498 ±10,566 ±9,118 ±9,173 55 Future G-5 ±10,644 ±10,671 ±9,235 ±9,256 21 Future G-5 ±10,686 ±10,730 ±9,268 ±9,302 34 Future B-4 HB-3 ±10,897 ±11,027 ±9,432 ±9,531 99 Future H K-3 B-1,3 10,902 10,985 9,436 9,499 83' 6 3/1989 B-4 10,998' 11,154' 9,509 9,627 156' 6 3/1989 B-5 HB-4 ±11,027 ±11,149 ±9,531 ±9,624 93 Future B-5 11,220 11,250 9,601 9,701 30' 6 3/1989 B-6 H8-5 ±11,194 ±11,300 ±9,658 ±9,739 106' 2 Future B-6 11,320 11,390 9,755 9,809 70' 2 10/1975 H K-5 HB-6 ±11,330 ±11,390 ±9,763 ±9,809 46 Future PBTD = 11,425'TD = 11,514' MAX HOLE ANGLE = 42°, KOP @ 400' Updated by: JLL 08/23/13 • • Well Work Prognosis Well: D-11 eaem!,v„k,.i.r.c Date: 08/26/2013 BOP Drawing • Hydril • 4.54' GK 13 5/8-5000 Il Iii iii Iillil .1_ Shaffer SL T — e 2.83' ' (Ca _ 13 5/8-5000 _ sir I 1'11IliliII Iii ��. ` �n . "4'101' r - 35/8_5„ � 2.00' 1 I ° 111 lil lil lil al Choke and Kill Valves 2 1/16 5M w/Unibolt connections for hoses 111 111 i!l ill in Riser 13 5/8 5M#13 API hub X 13 5/8 5M FE 17.00' Dolly Riser Xover 13 5/8 5M API#13 hub X 1.75' 111 111 11 5M Flange • • Well Work Prognosis Well: D-11 Hilcorp Alaska.III Date: 08/26/2013 Current Wellhead Diagram Tubing hanger,CIW-DCB- Dolly Varden FBB,11 X 4%]Armco Seal D-11 Lock lift and susp,w/4"type 13 3/8 X 9 5/8 X 3 1/2 H BPV,1/8 non continuous control line,7"extended neck prep BHTA,CIW,w/internal knockup cap,4 1/16 5M FE MAI 1.1 1.1 Valve,CIW-F,4 1/16 5M FE, ®0 HWO,EE trim =•4�•'�7 I.O. AIM/ „ 111111•10111.1111111111 Tree,Block,CIW-F,11 5M X i ' Q 'I 4 1/16 5M run X 3 1/8 5M _ \ �; wing,double master,wing \ _ valve,EE trim prepped for 7" r• • FBB type hanger neck,w/%Z control line exit _ III _ IlI Tubing head,CIW-DCB, III ICI 13 5/8 3M X 11 5M, Valve,CIW-F,2 1/16 5M FE, w/2-2 1/16 5M SSO, hi-i,. HWO,AA trim X bottom w/R seal installed 11111 :,' Void bad has been packed off III 111 Casing head,CIW WF, Valve,CIW-F,2 1/16 5M FE, 135/83MX 133/8 casing Ill HWO,AAtrim thread bottom,w/2-2 1/16 = = 1` _- 5M EFO 'I I 11'4'i II • • Well Work Prognosis Well: D-11 Hilrorj, tla'ka,LIT Date: 08/26/2013 New Wellhead Diagram Dolly Varden Tubing hanger,Seaboard- D-11 ESP-EN,11 X 3 1/2 EUE lift 13 3/8 X 9 5/8 X 3 1/2 and Susp w/3"Type H BPV profile,2-'''A CCL,Prepped for BIW penetrator BHTA,Bowen,3 1/8 5M X 2.5 Bowen quick union I n. Valve,Swab,WKM-M, �� ^�� 3 1/8 5M FE,HWO,DD trim `?/... ,u Q e', Valve,Wing,WKM-M,3 1/8 Valve,Wing,WKM-M,2 1/16 5M FE,w/15"OMNI 5M FE,HWO,DD trim ,.1 ... operator,DD trim [o` 01. . rmiow Valve,Master,WKM-M, -;t 3 1/8 SM FE,HWO,DD trim 9 > 000" Sn IMO MD L M m Adapter,Seaboard-ESP, 11 5M rotating flange x 3 1/8 5M rotating flange,w/ 4 11/16 pocket,w/2-'''A CCL, ported for BIW penetrator 01117-_--1114 Tubing head,S-8,13 5/8 3M _ii1o' �ein= x 11 5M,w/2-2 1/16 5M SSO,w/BG bottom 161 III w/1-2 1/16 SM WKM-M - - - A. - valves � - ° �' 1 i ill QI - 1/I .. Casing head,CIW-WF, I v- a Valve,CIW-F,2 1/16 SM FE, 13 5/8 3M X 13 3/8 casing I 1 — i Iil A HWO,AA trim thread bottom,w/2-2 1/16 = ,_C�i = �? 5M EFO 1 II® 1.1.11(11 ]]lite I.. • • Schwartz, Guy L (DOA) From: Roby, David S(DOA) Sent Tuesday,September 03, 2013 10:27 AM To: dmarlowe @hilcorp.com Cc: Schwartz,Guy L(DOA); Bettis, Patricia K(DOA) Subject Sundry application for TBU D-11 Dan, Part of the work proposed by your sundry application is to perforate a new pool and thus turn the subject well into a commingled producer. In the McArthur River Field commingled production involving the Hemlock, Middle Kenai "G", and West Foreland oil pools is authorized by CO 234A. Rule 3 of this order states: "Production logs shall be run within 2 months after initial completion to determine proper allocation of produced fluids. Additional logs should be run after significant changes to well mechanical configurations or abnormal, unexpected changes in well production characteristics. Results and copies of all logs will be filed with the Commission." Clearly with an ESP pump set above the perforated intervals a production log will not provide any useful information for allocation of production between the pools. The previous operator of this field, UNOCAL Corp.,had asked for a blanket waiver of this requirement for future wells, but via administrative approval CO 234A.001 the AOGCC approved the request for only two specific wells and stated "Rule 3 of CO 234A may be waived on a case-by-case basis for other wells." This administrative approval is still in effect. As such,we will need an application from Hilcorp for a waiver of the production logging requirement of CO 234A Rule 3 and a proposal for an alternative method of production allocation between the pools for the subject well. Regards, Dave Roby Sr.Reservoir Engineer Alaska Oil and Gas Conservation Commission (907) 793-1232 TO: THRU: FROM: Dan Seamount, ~/~~// DATE: Chairman Blair Wondzell, .~~ P. I. Supervisor Lou Grimaldi,~ ~ SUBJECT: Petroleum Inspector June 30,2000 No Flow Verification Unocal, Dolly Varden McArthur River Field D-5 PTD#168-028 Friday, June 30, 2000; I traveled to Unocal's Dolly Varden platform to verify the No- Flow status of wells D-5 and D-11 in the McArthur river field. I had been in contact with Greg checking on the wells status. I arrived to find both wells routed to the "Well Clean" tank which is the lowest back-pressure separator (approx. 2 psi) available on the platform. These wells had been open to well clean for twenty-four hours, bled down and both had negligible pressure on there production casing. 0800; D-5 & 11 flowing to well clean tank @ I psi, no fluid produced. Shut in flowlines D-5 0920; checked pressure 1 psi. 0950; pressure @ 1 psi establish rate at 200 scf/h 1025; pressure @ 1psi rate a 190 scf/h D-11 0925; checked pressure 1 psi. 0955; pressure @ 1.5 psi, establish rate at 200 scf/h 1030; pressure @ I psi rate at <180 scf/h. Note: 180 scf/hour is the lowest rate the flow meter could read. Both wells had no fluid production and slight gas flow but were below our 900 SCF/hour maximum. I recommend these wells be granted No-Flow status. Summary: I verified the No-Flow conditions on Unocal's wells D-5 and D-11 in the McArthur RiVer Field, Both wells passed. Cc; Bill Smith (Unocal Dolly Varden foreman) No Flow TBU UNOCAL D-5 D-11 6-30-00 LG ALASi~A OIL AND GAS CONSERVATION CO~ISSION / July 27, 2000 TONY KNOWLE$, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE. ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) .276-7542 Chris Meyers/Dwight Johnson UNOCAL Field Superintendents 260 Cavair Street · Kenai, Alaska 99611 Re: No-Flow Verification MRF Wells D-5RD and D-11 Gentleman: On June 30,2000, our inspector Lou Grimaldi witnessed "no-flow" tests on UNOCAL's .McArthur River Field TBU wells D-SRD and D-11. PriOr to his arrival, both wells had been routed to the "Well Clean" tank, which is about 2 psig back pressure. Both wells were bled down when Lou arrived and had been routed to the tanks forthe previous 24 hours. He ObserVed both Wells and recorded gas rates far below the "no- flow" limit of 900 scf/hr. He noted rates of 190 to 200 scf/hr on D-5 and 180 to 200 scf/hr on D-11. Neither well had any fluid production. He recommended that "no-flow" status be given to both wells. McArthur River Field TBU wells D-5RD (180-065) and D-11 (168-073) meet the criteria of a "no-flow" performance test and as such, are considered incapable of unassisted flow to the surface. Under the authority of 20 AAC 25.265(A) they are not required to have a fail-safe automatic SSSV: however, the pilot and surface safety valve must be maintained in good condition. If for any reason the well again becomes capable of unassisted flow of hydrocarbons, the subsurface safety valve must be returned to service. · .. Sincerely, Blair E. Wondzell/ '~Sr. Petroleum Engineer cc: Bill Smith (UNOCAL's Dolly Varden Foreman) 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~(l~ector 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 Platform in the McArthur River Field. 24 wells, 57 components tested, 3 failures witnessed. 5.2% failure rate. Attachments: SVS Dolly Pit. 6-22-00jc 'NON,CONFIDENTIAL SVS Dolly Pit. 6-22-00jc Alaska Oil and Gas Conservation Commission Safety Valve System Test Report Operator: Unocal Operator Rep: Mark Murietta AOGCC Rep: John Crisp Submitted By: John Crisp Date: Field/Unit/Pad: McArthur Rv./Dolly Var& Separator psi: LPS 110 HPS 6/22/00 Well Permit Separ Set L/P Test Test Test Oil, WAG, GINJ, 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 1830810 110 80 80 P P OIL :D-04RD 1820410 110 801 80 P P OIL iD-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 P P P ' OIL ~ 1680730 110 80 80 P P P OIL D-12RD 1800820 110 80 75 P P 43 OIL D-17RD 1810230 110 80 80 P P 43 OIL D-18 1690040 800 700 700 P P P GAS D-20 1690950 1101 80 90 P P OIL D-25RD 1780870 110! 80 100 P P OIL D-26RD 1981290 1101 80 75 P P OIL D-27 1750240 110 80 60 P P OIL D-28 1760360 110 80 100 P P OIL D-30RD2 1880980 D-31RD 1760740 110 80 70 P P 43 OIL D-32 1700370 110 80 75 P P P OIL D-40RD 1820830 110 80 80 P P 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% [-1 o0 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. 6-22-00jc 1 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: THRU: FROM: Dan Seamount, ~ 3,-~'~ jDATE: Chairman Blair Wondzell, J~~ ~.~k~/c~ P. I. Supervisor Lou Gri'maldi,~ ~ SUBJECT: Petroleum Insl~ctor June 30,2000 NO Flow Verification Unocal, Dolly Varden McArthur River Field D-5 PTD#168-028 D-11 PTD#168-073 NON,'CONFIDENTIAL Friday, June 30, 2000; I traveled to Unocal's Dolly Varden platform to verify the No- Flow status of wells D-5 and D-11 in the McArthur river field. I had been in contact with Greg checking on the wells status. I arrived to find both wells routed to the "Well Clean" tank which is the lowest back-pressure separator (approx. 2 psi) available on the platform. These wells had been open to well clean for twenty-four hours, bled down and both had negligible pressure on there production casing. 0800; D-5 & 11 flowing to Well clean tank @ 1 psi, no fluid produced. Shut in flowlines D-5 0920; checked pressure 1 psi. 0950; pressure @ 1 psi establish~ rate at 200 scf/h 1025; pressure @ 1 psi rate a 190 scf/h D-11 0925; checked pressure 1 psi. 0955; pressure @ 1.5 psi, establish rate at 200 scf/h 1030; pressure @ 1 psi rate at <180 scf/h. Note: 180 scf/hour is the lowest rate the flow meter could read. Both wells had no fluid production and slight gas flow but were below our 900 SCF/hour maximum. I recommend these wells be granted No-Flow status. Summary: I verified the No-Flow conditions on Unocal's wells D-5 and D-11 in the McArthur River Field, Both wells passed. Cc; Bill Smith (Unocal Dolly Varden foreman) No Flow TBU UNOCAL D-5 D-11 6-30-00 LG REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown: Stimulate: Plugging: Perforate: X Pull tubing: Alter casing: Repair well: Other: 2. Name of Operator 5. Type of Well:,,, 6. Datum elevation (DF or KB) UNOCAL Development: ..~ 106' KB ABOVE MSL feet 3. Address Exploratory: 7. Unit or Property name Stratigraphic: PO BOX 19@247 ANC, AK. 99519 Service: TRADING BAYUNIT 4. Location of well at surface Dolly Varden Platform, Leg A-2, Cond. if 3 8. Well number 761' FSL, 1132' FWL, SEC. 6 -8N - 13W -SM D-Il At top of productive interval 10901' 9. Permit number/approval number 514' FSL, 673' FWL, SEC. 32 - 9N - 13W - SM 68.073 At effective depth 11425' 10. APl number 830' FSL, 786' FWL, SEC. 32 - 9N - 13W - SM 50-733-20140-00 At total depth 11. Field/Pool 987' FSL, 848' FWL, SEC. 32 - 9N - 13W - SM · McArthur Rv. Field ! Hemlock 12. Present well condition summary Total depth: measured 11682' feet Plugs (measured) None true vertical 10021' feet Effective depth: measured 11425' feet Junk (measured) None true vertical 9828' feet Casing Length Size Cemented Measured depth True vertical depth Structural Conductor Surface 2,511' 13-3/8" 2400 SX 2,511' 2,339' Intermediate Production 9,691' %5/8" 2600 SX 9,691' 8,452' Liner 2,074' 7" 600 SX 11,514' 9,898' Perforation depth: measured ATTACHED true vertical Tubing (size, grade, and measured depth) 3.1/2", 9.3 #, L-80 TBG TO 10,822' Packers and SSSV (type and measured depth) BAKER 3H PKR. @ 10,745'; OTIS TR-I0 SSSV @ 310'.RECEIVED 13. Stimulation or cement squeeze summaryJAN2 $ 1998 Intervals treated (measured) Naska 0il & Gas Cons. Commission Treatment description including volumes used and final pressure Anchorage 14. Representative E~il~ ,~'~r~a~'Pl'(:ldl(~t~jl' ction Data OiI-BBL Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 1/2/1998 184 13 422 1202 120 Subsequent to operation 1/20/1998 221 0 647 1095 100 15. Attachments: 16. Status of well classification as: Copies of Logs and Surveys run: Daily Report of Well Operations: Oil: X Gas: Suspended: Service: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge: Signed: Dale Haines f ~ ~1 c~..~ Title: Drilling Manager Date: 1J21/1998 . Form 10-404 Rev 06/15/88 SUBMIT IN DUPLICATE TBU Well D-11 Perforations EXISTING OPEN PERFORATIONS: Bench Measured Depth True Vertical Depth HB-1,2,3 10,902' - 10,962' 9,428' - 9,493' HB-4 10,998' - 11,154' 9,502' - 9,620' HB-5 11,194' - 11,300' 9,651' - 9,733' HB-6 11,320' - 11,390' 9,749' - 9,803' NEW PERFORATIONS: 1/20/98 Reperforated Hemlock W/2-1/2" Hollow Carrier Guns, 6HPF, 0 Phase Zone Interval MD Feet,, Interval TV HB-1,2,3 10,870' - 10,985' 115' 9,502' - 9,493' HB-4 10,998' - 11,124' 126' 9,502' -9,597' TBU Well D-11 Perforations EXISTING OPEN PERFORATIONS: Bench Measured Depth True Vertical Depth HB-1,2,3 10,902' - 10,962' 9,428' - 9,493' HB-4 10,998' - 11,154' 9,502' - 9,620' HB-5 11,194' - 11,300' 9,651' - 9,733' HB-6 11,320' - 11,390' 9,749' - 9,803' NEW PERFORATIONS: 1/20/98 Reperforated Hemlock W/2-1/2" Hollow Carrier Guns, 6HPF, 0 Phase Zone Interval MD Feet Interval TV HB- 1,2,3 10,870' - 10,985' 115' 9,502' - 9,493' HB-4 10,998' - 11,124' 126' 9,502' -9,597' TBU Well D-11 Perforations EXISTING OPEN PERFORATIONS: ~Bench Measured Depth True Vertical Depth HB-1,2,3 10,902' - 10,962' 9,428'- 9,493' HB-4 10,998' - 11,154' 9,502' - 9,620' HB-5 11,194' - 11,300' 9,651' - 9,733' HB-6 11,320' - 11,390' 9,749' - 9,803' NEW PERFORATIONS: 1/20/98 Reperforated Hemlock W/2-1/2" Hollow Carrier Guns, 6HPF, 0 Phase Zone Interval MD Feet Interval TV HB-1,2,3 10,870' - 10,985' 115' 9,502' - 9,493' HB-4 10,998' - 11,124' 126' 9,502' -9,597' ,, Unocal North Amer 011 & Gas Division Unocal Corporation 909 West 9th Ave., P.O. Box 190247 Anchorage, Alaska 99519-0247 Telephone (907) 276-7600 Alaska Region UNOCAL RECEIVED APR 2 0 199~ Alaska Oil & Gas Cons. Commission DOCUMENT TRANSMITTAL April 16, 1993 TO- Larry Grant FROM: Kirk Kiloh LOCATION: 3OOl PORCUPIN DRIVE LOCATION: P.O.BOX 196247 ANCHORAGE, AK 99501 ANCHORAGE AK 99519 ALASKA OIL & GAS CONSERVATION COMM. UNOCAL TRANSMITIING AS FOLLOWS ' TRADING BAY UNIT 1 blueline and 1 sepia Logs from specified wells listed below %~0-~- D-5RD 6,9-q5' -- 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 STATE OF ALASKA 0 fl I 6 ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations oertormed: ODerat,on snutOown ~ St, mutate __ Plugging __ P'~rforate ~ Pull tubing ~ Alter casing ~ ReDa~r well ..__ Other ~ 2. Na~e of Operator I 5. Type of Well: . .. ! _ ,, Development ~ _ IINnCAI (Mn~n'l'hnn O'i 1 Cnmnnnv-~un-I).nen, aT. or) Exoloratorym 3. Adcl~es-s ' ' ~ n n ~ ~ A Straagra~ic ~ P.O. Box 190247 Anchorage,AKU~,,~J~i Service__ 4. Location of well at surface Leg A-2, Cond, #3 Dolly Varde'n Pla'ttorm 761' FSL, 1.131' FWL Sec. 6-8N-13W-SM At top pt procluct~ve mterva~ 514' FSL, 673' FWL, Sec. 32-gN-13W-SM At efiect~ve aepm 830' FSL, '786' FWL, Sec. 32-9N-13W-SM At total depth 987' FSL, 848' FWL, Sec. 32-gN-[3W-SH 12. Present well cond,tion summary Total depth, measured 11,682 ' feet true vert~cai 10,021' feet 6. Datum elevation (DF or KB) 106' KB above MSL feet 7. Unit or Property name Trading Bay Unit & Well numper D-11 9. Perrmt number/approval numDer 68-73 10. APl numDer 5o-- 733-20140 11. Field/Pool Hemlock Plugs (measured) None Effective aeptn measured 11 425 ' feet dun~ (measured) None [rue vertical ' feet 9,828' Casing Structural Conductor Surface Intermed)ate Production 9,6 91' 9 5/8" Liner 2,074' 7" Perforation depth measured Bench 1, 3 Bench 4 ~rue veracal Bench 5 Bench 6 Tubing (s~ze, grape, and measured depth) 3.5" 9.3#, EUE 8rd, L-80 AB Mod Butt PacKers and SSSV (type and measured depth) 7" 29# Baker ~H Perm Pkr w/ mi 1 lout 13. Stimulation or cement saueeze summary Length Size Cemented Measured deDth 2,511' 13 3/8" 2,400 sx 2,511' True vertical depth 2,339' Intervals treated (measured) Treatment description inctualng volumes used and final oressure Prior to well operation 2,600 sx 9,691' 600 sx 11,514' 10,902' - 10,985' MD 9,428' 10,988' - 11,154' MD 9,502' 11,194' - 11,300' MD 9,651' 11,320' - 11,390' MD 9,749' tbg to 10,821' ext 0 10,745', Otis Series 10 8,452' 9,898' 9,493' TVD 9,620' TVD 9,733' TVD 9,803' TVD TR SCSSV type FMX RECEIVED Subsequent to oDeraUon 15. Attachments Copies of Logs and Surveys run ~ Daily Report of Well Operations X Oil X Gas ~ 17. i nereOy certify mat the foregoing ~s true and correct to ~e best of my Knowledge. Form 10404 Rev 06/t5/88'-'" 425 88 507 1060 100 313 ~'~' 115 151 900 130 16. Status pt well c~aSmficat~on as: Suspended ~ Semce SUBMIT IN DUPLICATF DAILY WELL OPERATIONS D-Il 11/23/92 PT lubricator to 2500 psi, test good. Arm 16' of 1-11/16" pivot gun. 4SPF 10 deg phased. 90 deg offset. 22 g DP charges. RIH. Flow well 45 minutes when out of tubing for underbalance. Gun setting down in middle of existing HB-1 perfs. Work gently through on depth to reperf 10,940' - 10,955' DIL. Attempt to fire gun, no indication. S/I well and POOH. Did not fire. Scale and 1/2" pebbles in openings of gun housing. Order out 5' lubricator to avoid sticking gun at surface on remaining runs. RU 5" tree crossover and pump in sub w/ bullplug. PT to 2500 psi. Test good. Install remainder of lub w/ weight bars. PT to 2500 psi. Test good. Establish CBO and begin arming 15" pivot gun. Fire alarm in CB#2 room. Production shut-down on platform. Waiting on compressors. Still waiting on compressors. RD. 11/29/92 RU 5" lub. Held pre-job meeting. Install auxiliary pump on SCSSV w/ 4000 psi. PT lubricator to 2500 psi. PT good. Establish CBO. Arm 15' pivot gun (1- 11/16), 4SPF 180 deg. Phased 90 deg offset, 22 g DP charges. RIH w/ pivot gun. Could not get deeper than 10,940' Flowed well to obtain underbalance. RUN #1 HB-1 10,~25' - 10,940' DIL Fired .... #2 HB-1 10,910' - 10,925' DIL Misfired #3 HB-1 10,910' - 10,925' DIL Fired RD, put. well in test. 12/1-2/92 Install.aux pump on SCSSV 0 4000 psi. RU on tree and MU RB 9' stem, KJ, OJ, spangs 2.70" gauge ring. PT lubricator to 2500 psi. Test good. Open swab and RIH. Set down in top GLM. PU and fell trough. Continue RIH. Well apparently headed. Lower sheave hit the rig floor and wire parted about 12' above RS. POOH. Close swab. Break lub to find balled wire. No tools. 12' left on top of RS. Discuss options to fish tool. Run lead impression block. Could not locate top of tool. Make several attempts to fish. No success. Recovery of fish unlikely. RD slickline. Return well to production. H: \wp\WE L LOPS\D 11 RECEIVED DEC 2 2 1992 Alaska Oil & Gas Cons. Commission Anchorage ' ALASKA OIL AND GAS CONSERVATION COMMISSION · APPLICATION FOR SUNDRY APPROVA_ _ 1. Type of Request: Abandon __ Suspend ~ Operation shutdown __ Alter casing __ Repair well __ Change approved program __ 2. Nam. f~.p,f.~)l;)pratpz ..... ! 5. Tyl~e of Well: UPlUCAL kMara[non ui/ gompany-Sub-Opetator)Developmentm ..... · ----.----...--I Exploratory 3. Add~$~). BOX 190247 Anchorage, AK 9951(~ StratigraphicZ ~ Service I ,-,,-, ~_"9 r',,-,nrl #~ n,.,11,, ~ l ., ,,, ,.I ,., ,,, nl=+-Fnv, m bv~ ,i bI Will,4 . II~ S,,~ V I IJ ~ ~.4 I ~.4~.,f I I I 11,4v , vi ,,, 4. Location of well at surface 761' FSL, 1,131' FWL, Sec. 6-8N-13W-SM At ~ ~'~L, F~L, Sec. 32-ON-13W-SM to f,ro cvoig , Ate~bv~c~§r, 786' R~I_, Sec. 32-gN-13W-S~ Att°l;JcSe)eptl]:'SL, 848' FWL, Sec. 32-9N-13W-SM Re-enter suspended well Plugging ~ Time extension ~ ,~timulate __ Pull tubing ~ Variance ~ Perforate /~ Other __ 6. Datum elevation (DF or KB) 106' KB above MSL f._U_njt or Pro, l;)edy raalng i~ay ~et 8. Well number D-11 9. Permit number 68-73 10. APl number 2 14 5o- 733- 0 0 feet 12. Present well condition summary 11,682 ' Total depth: measured 10,021 ' feet true vertical feet Effective depth: measured 11,425 ' feet true vertical 9,828 ' feet Plugs (measured) Junk (measured) None None Casing Length Size Structural Conductor 2,511' 13 3/8" Surface Intermediate 9,691' 9 5/8" Production 2,074' 7" Liner Bench 1, 3 Perforation depth:measured Bench 4 Bench 5 true vertical Bench 6 Cemented Measured depth 2,400 sx 2,511' 2,600 sx 9,691' 600 sx 11,514' 10,902' - 10,985' MD 9,428' - 9,493' 10,988' - 11,154' MD 9,502' - 9,620' 11,194' - 11,300' MD 9,651' - 9,733' 11,320' - 11,390' MD 9,749' - 9,803' True vertical depth 2,339' 8,452' 9,898' TVD TVD TVD TVD Tubing (size, grade, and measured depth) 3.5" 9.3#, EUE 8rd, L-80 AB Mod Butt tbg to 10,821' Packers and SSSV (type and measured depth) 7" 29# Baker 3H Perm Pkr w/ millout ext 0 10.745'. Otis Series 10 TR SCSSV type FMX 13. Attachments Description summary of proposal ~ Detailed operations program A BOP sketch X 14. Estimated date for commencing operation 11/22/92 16. If proposal was verbally approved Mike Minder Name of approver 11/20/92 Date approved 15. Status of well classification as: ~ ~ ~, E I V r.= ~ Oil % Gas__ Suspen~c~d~ 7 ~992 Service ..~.!~-$k~ 0!! & G~s Corm. C0mmisSiOO 17. I hereby ce~fy that the foregoing is true and correct to the best of my knowledge. Signed ( ~,,.~~ ~_~, %,..._~ Title ~',.., L~, ,.~ ~~ FOR COMMISSIO~SE ONLY Conditions of a va,. ,,~tify Commission so representative may ~tness Plug integri~ __ BOP Test ~ L~ation clearance __ Mechanical Integri~ Test ~ Sub~quent form required 10- ?~ ~/ Approved by order of the Commission Original ~' olgned By David W. Johnston Anch0mgs Date ,t '-,I Approval No. ~,~,..,~ , ~ Commissioner Date Form 10-403 Rev 06/15/88 SUBMIT IN TRIPLICATE PROCEDURE NELL D- 11 Reperforate HB- 1 · · · · Obtain a 24-hour well test with minimum of four (4) WC's. Skid rig #77 over D-11 (Leg A-2). Hold safety/operational meeting. RU E-line unit. Hook up platform communication system in unit. Pressure test lubricator and BOPE to 2500 psi. - Apply 4000 psi control line pressure to the SCSSV with the auxiliary pump and monitor for any leak off prior to RIH. Pump to be located near lower wel 1 room entry door. NOTE: Prior to arming guns and until guns are 1000' in the hole, notify Logistic Support & establish communication black-out using the perforating check list. Re-establish the communication black-out when guns are @ 1000' when POOH. SI well. RIH with 1-11/16" pivot gun, 4 SPF 180 degree phasing and perforate the following intervals. Flow the well once the perforating guns are below the tubing tail to perforate underbalanced. RUN BENCH INTERVAL (DIL) FOOTAGE I HB #1 10,940' - 10,955' 15' 2 HB #1 10,925' - 10,940' 15' 3 HB #1 10,910' - 10,925' 15' · RD E-line unit. Return well to production and obtain a 24-hour well test w/ 4 WC's. H:\wp\WLPRO\D11 RECEIVED - 7 1892 Alaska Oii& Gas Cons, Commission Anchorage ~OLLY VARDEN pi.~")I'FORM Wireline Lubricator w/Associated BOPE~ GREASE HEAD (Hydraulically Activated) LUBRICATOR MANUALLY OPERATED BOP · 4'~1/.-1.6~.'$OOO psi CHISTMAS TREE -- POSITIVE CHOKE RECEIVED DEC - 71~'" Alaska Oii & Gas Coa~. Commissiof~ Anchorage ----- 2" 5000 pal --- 2' 3000 pal ,, 13 3/8' CASING Compieted 03/16/89 MARATHON OIL COMPANY TRADING BAY UNIT WELL D-ii ALL measurements are RKO to top oF equipment, 48,8' Cameron 'F' Tbg, Hngr, 4,5' ASL Top, X Botm, 370' Otis 3,5' Series 10 TR SCSSV Type FHX (2,813' ID), Comptetlon String: 0'-10,881' 3.5' 9.3~, EUE 8rd, L-80 AB Mod Butt Tbg. Gas lift mandrels are 3,5' CAMCO MMG II (2.867' ID) w/AB Mod EUE 8rd couplings, VaWes are GLESCn R-PO 1,5' w/RK latches, Yalve ~9 is orifice type, 13-3/8' Csg 61~ J-55 @ 2511' TDL 7' @ 9440' 9-5/8' Csg 40, 43.5, 47~ N-80 & RS-95 Cs9 @ 9691' 8477' ~1 16/64 Port 4646' ~8 16/64 Port 6814' ~3 16/64 Port 7341' ~4 20/64 Port 7978' ~5 16/64 Port 8561' ~6 84/64 Port 9144' ~7 88/64 Port 9752' ~8 88/64 Port 10,359' ~9 88/64 OriFice 10,731' 10,731' 10,745' 10,756' 10,788' 10,881' Baker Seat AsseMIoLy Locator & sea~ assembly (18.009. B~iker PBR w/'CH' Anchor Latch 7" 89ff Baker 3H Perm Pkr w/mlUout ext (4.5" EUE 8rd Pin x Pin) 4.5' x 3.5' XD (Srd Box x EUE 8rd) Otis 'XN' NippLe (8,813' ID) w/8.75' NoGo B~ker Sheorout Sub. Csg P9~ N-80 11,514' B-l, 3 B-4 B-5 B-6 B-l, 3 B-4 B-5 B-5 B-6 PBTD @ 11,485' TD 8 11,514' PerForations 10,908'-10,985' 6 SPF 180' Phasing 03/89 10,998'-1L154' 6 ' 11,220'-1L250' 6 ' 11,194'-11,300' 2 0° Phasing 10/75 11,320'-11,390' 8 0° Phasing 10/75 RECEIVED OEO - 7 i992 Alaska OJj & Gas. C0rls. Commissior~ Anchorage Revision Date: 5/1/90 Revised By: NEF Reason: Change GLV's Previous Revision: 3/81/89 Unocal North American Oil & Gas Division Unocal Corporation P.O. Box 190247 Anchorage, Alaska 99519-024 Telephone (907) 276-7600 UNOCAL Alaska Region DOCUMENT TRANSMITTAL December 1, 1992 TO' Larry Grant LOCATION: 3001 PORCUPINE DroVE ANCHORAGE, AK 99501 ALASKA OIL & GAS CONSERVATION COMM. FROM: Kirk Kiloh LOCATION' P.O.BOX 196247 ANCHORAGE AK 99519 UNOCAL TRANSMITTING AS FOLLOWS TRADING BAY UNIT D-7, D-Il, D-12RD, D-25RD 1 blueline and 1 sepia Perforating Record PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY OF THIS DOCUMENT TRANS~VIITTAL. THANK YOU II DATED: -,-, ~'~ ~9~.~- Alaska 0tl & Gas Cons. Commission Anc~rage ) ) 0 R ^.,.s.^ CO ,S..V^T,O, REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown Stimulate __ Plugging m PerforateX Pull tubing __ Alter casing m Repair well __ 2. Name of Operator I 5. Type of Well: , ,, / _ ~ Development ..X_ UNOCAL (Marathon Oil. ComDanv-Sun-upena~;or} Exploratory Other 3. Address Stratigraphic P.0. Box 190247 Anchorage, AK 9951 Service~ 4. Location of well at surface Leg A-2, 6ond. #3 Dolly Var'den Platform 761' FSL, 1,131' FWL Sec. 6-8N-13W-SM At top of productive interval ' 514' FSL, 673' FWL, Sec. 32-9N-13W-SM At effective depth 830' FSL, 786' FWL, Sec. 32-9N-13W-SM At total depth 987' FSLf 848' FWLf Sec. 32-9N-13W-SM 12. Present well condition summary Total depth: measured 11,682 ' feet Plugs (measured) true vertical 10,021' feet Effective depth: measured 11 425 ' feet true vertical ' feet 9,828' Casing Length Size Cemented Structural Junk (measured) 6. Datum elevation (DF or KB) 106' KB above M§L 7. Unit or Property name I n M Ull i l,~ ~. nme D.11 feet 9. Permit number/approval number 92-0.55//'~,.,-~,'~.¢: ~/,m'- 10. APl numb~'r 50/33-20140 Measured dePth 11. Field/Pool Hemlock R None VOV 2 None Alaska Oil &~ ~._ _Gas Coas. True ve~ical depth Conductor Surface 2,511' 13 3/8" 2,400 sx Intermediate 2,511' 2,339' Production 9,691' 9 5/8" 2,600 sx Liner 2,074' 7" 600 sx Perforation depth:measured Bench 1, 3 10,902' Bench 4 10,988' true vertical Bench 5 11,194' Bench 6 11,320' Tubing (size, grade, and measured depth) 9,691' 8,452' 11,514' 9,898' - 10,985' MD - 11,154' MD - 11,300' MD - 11,390' MD 9,428' 9,502' 9,651' 9,749' - 9,493' TVD - 9,620' TVD - 9,733' TVD - 9,803' TVD p~k~r"sa~d~V(~[a~t~easl, u-.i~Ode~)Mod Butt tbg to 10,821' 7" ?q# Baker 3H Perm Pkr w/ mill out ext @ 10 745' 13. Stimulation or cement squeeze summary Intervals treated (measured) 0t, i s Seri es 10 TR SCSSV tvoe FMX - . Treatment description including volumes used and final pressure 14. Prior to well operation Representative Daily Average Production or Injection Data OiI-Bbl Gas-Md Water-Bbl Casing Pressure 504 ¢/~ 119 476 940 Tubing Pressure 100 Subsequent to operation 515 / 190 496 15. Attachments I Copies of Logs and Surveys run __ Daily Report of Well Operations _Z. Oil X_._ Gas __ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed (~~ %, ~-'b,-,,-,'~, Title %~\~,~ 900 16. Status of well classification as: Suspended © Service 120 Date ~\/~'h !'~ 't~ SUBMIT IN DUPLICATE DAZLY I/ELL OPERATZONS D-11 2/29/92 Held pre-job meeting. HLS RU on D-11. Tag out SCSSV on control panel. Pt lub to 2500 psi. Good. Established CBO. MU 2-1/8" strip gun, 4 SPF, O-phase, 30 offset, 20.5 gram. RIH w/ 25' strip gun. Did not set guns down, deepest depth = 11,347' DIL. Unable to fire gun. POOH. Re-est CBO @ 1000' ELM. To surface with gun. Pull off gun in lubricator, depth indicator reading 117'ELM. Rig down lubricator. Secure well. Return to production. 3/1/92 Rig up HLS lubricator to tree and cross over to Otis lubricator. Hold pre-job meeting. Emphasize safety procedures & CBO for live guns to the surface. Tag out SCSSV on control panel. PT lub to 2500 psi. Good test. RIH with fishing tools. Sat down on fish at 11,336' WLM. Latch fish. POOH slowly. Disarm and LD guns. Otis rigged off. HLS rig up. PT lubricator to 2500 psi. PT good. RIH to 4700' POOH & log #1 & #2 GLM. Depths OK. BV on depth. Establish CBO. MU & arm 30" 2-1/8" strip gun, 4 SPF. 0 phasing, 30 offset, 20.5 gr. RIH. Flowed well to obtain underbalance & perforated the following intervals: RUN #1 HB-5 11,250' - 11,280' #2 HB-5 11,220' - 11,250' #3 HB-1 10,932' - 10,962' #4 HB-1 10,902' - 10,932' RD. Return well to production. F i red F i red F i red F i red H: \wp\WELLOPS\D 11 ..~ STATE OF ALASKA ~ ALASKA IL AND GAS CONSERVATION C~.~MISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG Classification of Service Well 1. Status of Well .. .. · . , . OIL~[] G~S [] SUSPENDED [] ABANDONED [] SERVICE [] ~2. Name of Operator 7. Permit Number UNOCAL (Marathon 0il Co. Sub-operator) 68-73 3. Address 8. APl Number · P. 0. Box 190247 Anchorage, AK 99519 5o- 733-20140-,~j~r 4. Locat~o, ofwe, atsurface Leg .A-2, Cond. #3 Dolly Varden Platform 9. Un~t or Lease Name 761' FSL, 1,131' FWL, Sec. 6 8N-13W-SM Tradin9 Bay Unit At Top ~roducin§ lnterval 10. Well Number 514' FSL, 673' FWL, Sec. 32 9N-13W-SM D-II At Total Depth 11. Field and Pool 987' FSL, 848' FWL, Sec. 32 9N-13W-SM McArthur River Field .§. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. 106' KB above MSL] ADL 17594 Hemlock Pool 12. Date Spudded 13. Date T.D. Reached 14. Date Comp:, Susp. or Aband. 15. Water Depth, if offshore 16. No. of Completions 8/31/68 10/8/68 : 3/16/89 , '132' feet MSL 1 17. Total Depth (M D+TVD) 18.Plug Back Depth (MD+'I'VD) 19. Directional Survey I 20. Depth where SSSV set I 21. Thickness of Permafrost 11682' - 10021' 11,425' 9828' YES[] uO)~'1 370' feetMD] N/A 22. TYpe Electric or Other Logs Run None 23. CASING LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 13-3/8" 61# J-55 0' 2,511,' 17.5" 2400 s× Class G . N/A 9-5/8" 40, 43.~ N-80 & 0' 9,691' ]2 25!'- 2600 sx £1as~ G N/A 47# RS-95 7"Liner 29# N-80 9440' 11,514' 8.5" 600 sx Class G N/A 24. Perforations open to Production (MD+TVD of Top and Bottom and ,25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) - PACKER SET (MD) B-I, 3 10,g02-10,985' MD,. 9428-9493' TVD 3.5" 10~71' !0,745' B-4 10,998-11,154' MD, 9502-9620~ TVD . B-5 11,194-11,300' MD, 9651-9733' TVD 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. B-6 11,.~20-]1,390' .MD,. 9749-9803'... T. VD DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED , · 27. PRODUCTION TEsT Date F irstf/~t~ . ] Method of Operation (FIo_vvin§, g~i I~, etc.) "' ' ' ' Gas .. ' D~7 ft~ H°urs t~sted TEsTPRODUCTION FORpERiOD ~ O, L-BBL64 GAS-MCF24.5 WATER-BBL228 CHOKE SiZENA ] GAS-OIL RATIO375 Flow Tubing CaS~f(~)essure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 130 2..4-HouR RATE.~ 128"" .49 456 34" " - 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. None , .... ~ .... 0il & Gas.C~.ns, . Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE , . GEOLOGIC MARKERs ' ~' ' :FORMATION TEsTs'"' , NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH . GOR, and time of each phase. , , Hemlock' Top 10,901' 9,427' None · · · ... · 31. LIST OF ATTACHMENTS Attachment #1 Current Wellbore Di,agram 32. I hereby certify that the foregoing is true and correct tothe best of my knowledge Signed ~ /~- ~/~' ¢.g~,-,~_-~ ' ~~,. ~'~'~¢.,, Date ~.~"--~ ~"~ ' ~z~.~ Title INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells' Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5' Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be serparately prodUced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. ! Item 27: I~et"~od of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28' If no cores taken, indicate "none".' Form 10-407 Attachment #1 MARATHON []IL C[]MPANY TRADING BAY UNIT ~/ELL D-11 CompLeted 03/16/89 measurements are RKB to top o? equipment, 42.2' Cameron 'F' Tb§. Hngr. 4.5' ASL Top, X Botm. 370' Otis 3,5' Series 10 TR SCSSV Type FMX (2,813' ID), Comoletlon 0'-10,881' 3,5' 9,3#, EUE 8r~ L-80 AB Hoc; Butt Tbg, Gas II?t mandrels are 3,5' CAMCO MMG II (2,867' ID) w/AB Mod £UE 8rd couplings. Valves ore CAMCO R-20 1,5' w/RK latches, Valve #9 Is orifice type, 13-3/8' Cs9 61# J-55 @ 2511' TOL 7' @ 9440' 9-5/8' Csg 40, 43,5, 4715 N-BO ~& RS-95 Cs9 ~ 9691' 2477' 441 12/64' Port 4646' 442 12/64' Port 6214' fl3 12/64' Port 7341' ~4 16/64' Port 7978' ~5 16/64' Port 8561' ~6 16/64' Port 9144' t57 16/64' Port 9752' fib 20/64' Port 10,359' #9 20/64' Orl?lce 10,731' 10,731' 10,745' 10,756' 10,788' 10,821' Baker Sea[ Assembly Loca%or & sea[ assembly (12.00'). Baker PBR w/'CH' Anchor La,ch 7' 29ff Baker 3H Pemm Pk~ ~/ml[[ou~ ex% (4.5' EUE 8md Pin x Pin) 4.5' x 3.5' XB <8~d Box x EUE B~is 'XN' Nipple (~.8~3' ID) w/~.75' NoGo Baker She~rout Sub. 7' Cs9 2944 N-80 @ 11,514' B-1,3 B-4 B-5 B-6 3-1,3 B-4 B-5 B-5 3-6 PBTD @ 11,425' ID 8 11,514' PerForations 10,902'-I0,985' 6 SPF 120' Phasing 03/89 10,998'-11,154' 6 ' ' 11,220'-11,250' 6 ' 11,194'-11,300' 2 0° PhosIn9 10/75 11,320'-11,390' 2 O' Phos~n9 10/75 Revision ])ate: 3/21/89 Revised By: MRD/ne? Rea so n, Re compte tlon Previous Revision~ 9/87 Marathon Oil Company ,o nR I G I Domestic Proddeti0h' RO. Box 190168 Anchorage, Alaska 99519 Telephone 907/561-5311 March 4, 1992 Ms. Lynn Woodruff UNOCAL P.O. Box 190247 Anchorage, AK 99519 Dear Ms. Woodruff: Enclosed for further handling is the AOGCC "Application for Sundry Approval" for wells D-7RD, D-11, D-12RD, and D-25RD. Should you have any questions regarding any application or report, please contact Mr. Ed Oberts at (907) 564-6436. S i ncerel y, Operations Engineering Supervisor ~docs\ml\7.doc A subsidiary of USX Corporation AS)K STATE OF ALASKA 0 R I G I N A L AL "A OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon __ Suspend __ Alter cas, ng __ Repair well __ Change approved program __ 2. Name of Operator / 5. Type of Well: UNOCAL (Marathon Oil Company-Sub-Operator) Development X , , Exploratory __ 3. Address ! Stratigraphic m P.O. Box 190247 Anchorage, Al( 9951~9 Service__ Operation shutdown __ Re-enter suspended well __ Plugging __ Time extension __ .$timulat Pull tubing __ Variance __ Perforate..~ %"~r ~ FWL, Sec. 32-9N-13W-SM FWL, Sec. 32-9N-13W-SM FWL, Sec. 32-9N-13W-SM 4. Location of well at surface Leg A-2, Cond. #3 Dolly Varden Platform 761' FSL, 1,131' FWL, Sec. 6-8N-13W-SM At top of productive interval 514' FSL, 673' At effective depth 830' FSL, 786' At total dep. th 987' FSL, 848' 6. Datum elevation (DF or KB) 106' KB above HSL 7. Unit or Property name Tradino gav Ilnit 8, Well number D-11 9. Permit number 68-73 10. APl number 50-733-20140-00 11. Field/Pool Hemlock feet 12. Present well condition summary Total depth: measu red true vertical 11,682 ' feet Plugs (measured) 10,021' feet Effective depth: measured true vertical 11,425' feet Junk (measured) 9,828' feet Casing Length Structural Conductor Surface 2,511' Intermediate Production 9,691 ' Liner 2,074' Perforation depth: measured true vertical Size Cemented Measured depth None R CEIVED None ?viAR ~ · ../as~ea.Djl.& Gas Cons, '' ~~ldepth 13 3/8" 2,400 sx 2,511' 2,339' 2,600 sx 9,691' 8,452' 600 s.x 11,514' 9,898' Tubing (size, grade, and measured depth) g 5/8" 7" Bench 1, 3 Bench 4 Bench 5 Bench 6 10,902' - 10,985' MD 10,988' - 11,154' MD 11,194' - 11,300' MD 11,320' - 11,390' MD 9,428' - 9,493' TVD 9,502' - 9,620' TVD 9,651' - 9,733' TVD 9,749' - 9,803' TVD 3.5" 9.3#, EUE 8rd, L-80 AB Mod Butt tbg to 10,821' Packers and S~SS,V (type and measured depth) 7" 29# uaKer 3H Perm Pkr w/ millout ext 0 10,745'0 Otis Series 10 TR SCSSV type FMX 13, Attachments #1, 2, Description summary of proposal &3 Detailed operations program BOP sketch _._X 14. Estimated date for commencing operation 2/29/92 16. If proposal was verbally approved Mi ke Mender Name of approver 2/28/92 Date approved 15. Status of well clasSification as: Oil X Gas ~ Suspended __ Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed CX o..,.¢~ ~. ~-"2 u.4:~', Title ' ff'~ O FOR COMMISSK)N 'Conditions of a~roval: Notify Commission so representati've may witness Plug integrity ~ BOP Test ~ Location clearance Mechanical Integrity Test ~ Subsequent form required 10- Approved by order of the Commission ORIGINAL SIGNED BY LONNIE C. SMITH I Appr,o. val No. <::] <,,O- O ~ 5 q:)pr ov,~:;~i, Copy Retu ri'ied _3-;~ 5- '~, Commissioner Date Form 10-403 Rev O6/15/88 SUBMIT IN TRIPLICATE ¢' Attachment # 1 Reperforation Procedure DVP Well D-11 1) 2) 3) 4) 5) 6) 7) Obtain a 24-hour test with a minimum of four (4) WC's. Test tree valves and ensure operational and holding. Skid rig #77 over D-11. Conduct safety meeting. Ensure adequate lighting for night operations. Disconnect SCSSV from manifold and lock open SCSSV with auxiliary pump on platform. Regulate pressure between 3700 - 4000 psi. Ensure control line pressure does not bleed off. RU E-Line unit. Hook up platform PA system in unit. Install new packoff in lubricator prior to start of job if the age is unknown. Pressure test lubricator and BOPE to 2500 PSI. NOTE: PRIOR TO ARMING GUNS AND UNTIL GUNS ARE 1000' IN THE HOLE, NOTIFY LOGISTIC SUPPORT & ESTABLISH COMMUNICATION BLACK-OUT. RE-ESTABLISH THE COMMUNICATION BLACK-OUT WHEN GUNS ARE @ 1000' WHEN POOH. SI WELL TO RIH & POOH. RIH with 2-1/8" strip guns, 4 SPF, 0° phase, and perforate the following intervals underbalance: RUN BENCH INTERVAL (DIL) FOOTAGE 1 HB #1 10,932' - 10,962' 30' 2 HB #1 10,902' - 10,932' 30' 3 HB #5 11,250' - 11,280' 30' 4 HB #5 11,220' - 11,250' 30' RD E-Line unit. Return well to production and obtain several 12-hour well tests obtaining 3 WC's per 12-hour test. \dvp\il.doc RECEIVED , ~chomge P,'~tachment ~,"2 MARATHON 0IL COMPANY TRADING BAY UNIT WELL D-ii CompLeted 03/16/89 AlL measurements are RKB ~o top oF equipment. 42.2' Cameron 'F' Tbg. Hngr. 4.5' ASL Top, X Botm, 370' Otis 3.5' Series 10 TR SCSSV Type FMX (2.813' ' CompLe~lon S~rlnq, 0'-10,821' 3.5' 9.3~, EUE 8rd, L-80 AB Mod 3utt Tbg. G~s I;¢t Mandrels are 3.5' CAMCO MMG II (2.867' ID) w/AB Mod EUE 8rd couplings. V~Lves are GLESCD R-80 1,5' w/RK t~ches, Valve ~9 ;s orifice type, 3-3/8' Csg ,I~ J-55 :' 8511' ~OL 7' ~_ 9440' )-5/8' Csg ;0, 43,5, 47W '1-80 & RS-95 ]sg @ 9691' 7' Csg P_9% N-80 ? 11,514' B-l, 3 B-4 2477' ~1 16/64 Port 4646' ~8 16/64 Por~ 6814' ~3 16/64 Port 7341' ~4 20/64 Port 7978' ~5 16/64 Port 8561' ~6 24/64 Port 9144' 97 28/64 Port 9752' ~8 28/64 Port 10,359' ~9 88/64 OriFice 10,731' 10,731' 10,745' 10,756' 10,788' 10,881' B-1,3 B-4 B-5 B-5 B-6 B-5 B-6 PBTD 8 11,425' TD 8 11,514' B0.ker Seat AsSembLy Locator & seal asSembLy (1P.O0'), B6ker PBR w/'CH' Anchor L&tch 7' 89~: Baker 3H Perm Pkr w/miltout ext (4,5' EUE 8rd Pin x Pin) 4,5' x 3,5' XF1 (Srd Box x EUE 8rd) Otis 'XN' Nipp(e (~,813' ID) w/8,75' NoGo B6ker She6rout Sub, Per?orations i0,902'-10,985' 6 SPF 180' Phasing 03/8' 10,998'-11,154' 6 ' ' 11,220'-11,250' 6 ' · 11,194'-11,300' P O' Phasing 10/77 11,320'-11,390' 2 O' Phasing 10/77 Revision Date, 5/1/90 Revised By: NEF Reason, Change GLV's Previous Revision: 3/21/89 Attachment Wireline Lubricator w/Associated BOPE MANUALLY OPERATED BOP · 4' ~11;1.6 -'.. 5000 psi CHISTMAS TREE - GREASE HEAD (Hydraulically Activated) ...... LUBRICATOR POSITIVE CHOKE 2' 5000 psi 2' 3000 psi · 13 3/8' CASING DOLLY DISTANCE & DIRECTIONS FROM SE CORNER SEC. 6, TSN, R13W CONDUCTOR "Y" COORD. "X" COORD. LEG #A-1: LAT -- 60°48' 28.272" LONG :151°37' 57.620" 2,490,836.22 208,461.20 WELL # FSL FWL 757.5 1 2 3 4 5 6 7 8 9 10 ll 12 2,490,836.95 2,490,840.99 2,490,842.79 2,490,841.51 .2,490,837.76 2,490,833.28. 2,490,830.18 2,490,829.90 2,490,832.58 2,490,835.56 2,490,838.66 2,490,834.00 208,454.55 208,456.66 208,460.79 208,465.ll 208,467.60 208,467.10 208,463.83 208,459.34 208,455.72 208,458.66 .208,462.17 208,462.61 1212.0 LEG #A-2: 1 2 3 4 5 6 7 8 9 l0 ll 12 2,490,835.42 2,490,836.16 2,490,840.19 2,490,842.00 2,490,840.72 2,490,836.97 2,490,832.49 2,490,829.39 2,490,829.11 2,490,831.78 '2,490,834.77 2,490,837.86 2,490,833.21 208,381.20 208,374.66 208,376.67 208,380.80 208,385.11 208,387.60 208,387.10 208,383.84 208,379.34 208,375.72 208,378.66 208,382.17 208,382.61 D-27 758.1 1205.5 D-28 762.1 1207.4 D-29 764.0 1211.5 -D-32 762.9 1215.8 D-40 759.2 1218.4 D-41 754.7 1218.0 D-26 751.5 1'214.8 D-25 & RD 751'.1 1210.3 753.7 1206.7 D-24 & 34A 756.8 1209.5 D-31 & RD 760.0 1213.0 D-24A 755.3 1213.5 754.7 LEG #B-l' LAT -- 60°48' 27.485" LONG :151°37' 57.564" 2,490,756.22 208,462.00 D-1 755.3 D-17 759.4 D-11 761.3 D-7 & RD 760.1 D-9 756.4 D-19 751.9 D-23 748.8 D-21 748.4 D-5 & RD 750.9 D-15 & RD.& 2 754.0 D-3 & RD 757.2 D-13 752.5 1 2 3 4' 5 6 7 8 9 10 ll 12 2,490,755.48 2,490,751.45 2,490,749.65 2,490,750.92 2,490,754.67. 2,490,759.15 2,490,762.25 2,490,762.53 2,490,759.86 2,490,756.87 .2,490,753.78 2,490,758.43 208,468.53 208,466.53 208,462.40 208,458.08 208,455'.59 208,456.10 208,459.36 208,463.85 208,467.48 208,464.53 208,461.02 208,460.58 677.5 LEG #B-2: 2,490,755.43 208,382. O0 (Reserved for Compressors) D-8 & RD 677.0 D-6 672.9 D-14 & RD 671.0 D-20 672.1 D-16 675.8 D-22 680.3 D-2 & A & RD 683.5 D-4 683.9 D-10 681.3 D-12 & RD 678.3 D-18 675.1 D-30 & RD 679.7 674.8 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 1221.4 121'9.5 1215.4 1211.1 1208..5 1 208.9 1212.1 1216.5 1220.2 1217.4 1213.9 1213.4 1134.9 Unocal North Americ 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, Gar~. S.(~ush Regional Drilling Manager GSB/lew REPORT OF SUNDRY WELL OPERATIONS 1. Operations pedormed: Operation shutdown __ Stimulate ~ Plugging __ Perforate Pull tubing __ Alter casing __ Repair well __ 2. Name of Operator ! 5. Type of Well: UNOCAL (Marathon Oil Company-Sub-dperatop~velopment~ ~ Exploratory ~_ _ , ! Stratigraphic 3' Address p. 0. Box 190247 Ancnorage, AK 9~519 Service--~ 4. Location of well at surface Leg A-2, Cond. #3 Do]ly Varden Platform 761' FSL, 1,131' FWL, Sec. 6-8N-13W-SM At top of productive interval 514' FSL, 673' FWL, Sec. Ateffecti~3d(~ptl¥sL, 786' FWL, Sec. Attotald~l~, FSL, 848' FWL, Sec. 32-9N-13W-SM 32-9N-13W-SM 32-9N-13W-SM Other 6, Datum elevation (DF or KB) 106' KB above MSL 7. Unit or Property name feet Trad ~ nn Bay U.n.'i f 8. Well ~6m'b6r ' - D-11 9. Permit number/approval number 9-342 10, APl number 5o- 733-20140-01 11. Field/Pool Hemlock 12. Present well condition summary Total depth: measured true vertical 11,682' 10,021' feet feet Plugs (measured) None Effective depth: measured 11,425 ' true vertical9,828' feet feet Junk (measured) None Casing Length Structural Conductor Surface 2,511 ' Intermediate Production 9,691 ' Liner 2,074' Perforation depth:measured true vertical Size 13 3/8" 9 5/8" 7" Bench 1, 3 Bench 4 Bench 5 Bench 6 Tubing (size, grade, and measured depth) 3.5" L-80 @ 10,821' Packers and SSSV (type and measured depth) Baker "3H" Perm Pkr @ ]0.745'. 13. Stimulation or cement squeeze summary Cemented Measured depth 2,400 sx 2,511' 2,600 sx 600 sx 9,691' 11,514' 10,902' 10,998' 11,220' 11,320' - 10,985' MD - 11,154' MD - 11,250' MD - 11,390' MD Otis "Sories ]n TP" ~;C_,~qV ¢ 3_70, 9,428' 9,501' 9,684' 9,749' Intervals treated (measured) See Attachment #1 Treatment description including volumes used and final pressure True vertical depth 2,339' 8,452' 9,898' - 9,505' TVD - 9,620' TVD - 9,707' TVD - 9,803' TVD RECEIVE 14. Representative Daily Average Production or Injection Data OiI-Bbl Gas-Md Water-Bbl Casing Pressure Tubing Pressure Prior to well operation Subsequent to operation 5/3/89 107 16 350 1060 5/24/89 121 16 469 1150 140 110 15. Attachment¢ ¢? 1 16. Status of well classification as: Copies of Logs and Surveys run ~ Daily Report of Well Operations x Oil 7, Gas ~ Suspended "'i7. I hereby certify that the foregoing is true and correct to the best of my knowledge. / o' Roy D Form 10-404 Rev 06/15188 ' Roberts Title Environmental Engineer Service Date 6/21/89 SUBMIT !N DUPLICATE Attachment # Daily Summary of Operations 5/7/89 TBU Well D-11 RU pumping equipment and test lines. Pump 500 gal 15% HC1 pickle acid with 85% xylene and 20#/1000 gal L-58. Displace to EOT w/ FIW. Produce back pickle acid and flow well until clean. Shut well in and pump the following treatment' Volume Fluid 1250 gal Xyl ene 300 " NH4CL foam 1250 " Xylene 300 " NH4CL foam 1250 " Xyl ene 300 " NH4CL foam 1250 " Xylene Displace to perforations w/ 3% NH4CL. Final injection pressure was 2650 psi @ 1.6 BPM. Allow xylene to soak. 5/8/89 Mixed and pumped the following treatment' Volume Fluid 1250 gal 7-1/2% HC1 w/ 5% EGMBE, 20#/ 1000 gal L-58, 0.2% F-75N + 0.2% A-250 300 " 1250 " 300 " 1250" 300 " 1250 " NH4CL foam 7-1/2% HC1 + additives NH4CL foam 7-1/2% HC1 + additives NH4CL foam 7-1/2% HC1 + additives RECEIVED 2 6 . Sg Displace to perforations w/ nitrified NH4CL. Treatment pumped @ 2700 psi but broke back to 1300 psi when acid reached perforations. SI well, RD, place well back on production. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon __ Suspend __ Alter casing __ Repair well __ Change approved program __ Pull tubing m Variance __ 2. Name of Operator ! 5. Type of Well: UNOCAL (Marathon Oil Company-Sub-Operator) De..vel,opm. ent__ / ~-xp~ora~ory __ 3. Address ' I Stratigraphic __ P.O. Box 190247 Anchorage, AK 9951E[ Service__ 4. Location of well at suFface Leg A-2, Cond. #3 Dolly Varden Platform 761' FSL, 1,131' FWL, Sec. 6-8N-13W-SM At top of productive interval 514' FSL, 673' At effective depth 830' FSL, 786' At t°t~dTeJ;:)t hF S b, 848' Operation shutdown m Re-enter suspended well ~ Plugging __ Time extension ~ Stimulate X Perforate ~ Other 6. Datum elevation (DF or KB) FWL, Sec. 32-9N-13W-SM FWL, Sec. 32-9N-13W-SM FWL, Sec. 32-gN-13W-SM 106' KB above MSL feet 7. Unit or Property name Tradino Ray Unit 8. Well n~mber' D-11 9. Permit number 10. APl number 5o-7-33-Z0140-01 11. Field/Pool Hemlock None 12. Present well condition summary Total depth: measured 11,682 ' feet Plugs(measured) true vertical 10,0 21 ' feet Effective depth: measured 11,425 ' feet Junk (measured) true vertical 9,828' feet Casing Length Size Cemented Structural Conductor Sudace 2,511' 13 3/8" 2,400 SX Intermediate Production 9,691' 9 5/8" 2,600 SX Liner 2,074' 7" 600 sx Perforation depth:measured Bench 1, 3 10,902' Bench 4 10,998' true vertical Bench 5 11,220' Bench 6 11,320' Tubing (size, grade, and measured depth) 3.5" L-80 @ 10,821' Packers and SSSV (type and measured depth) Baker "3H" Perm Pkr @ 10,745', 13. Attachments Description summary of proposal None Measured depth True vertical depth 2,511' 2,339' 9,691' 8,452' 11,514' 9,898' - 10,985' MD - 11,154' MD - 11,250' MD - 11,390' MD Otis "Serie~ 10 TI{" SCSSV @ 370' Detailed operations program ~ 9,428' - 9,505' TVD 9,501' - 9,620' TVD 9,684' - 9,707' TVD 9,749' - 9,803' TVD BOP sketch __ 14. Estimated date for commencing operation 5/8/89 "16. 'If proposal was verbally approved Oil .~X Gas __ Name of approver Date approved Service 17. I_hereby certi~ that the/foregoinQ is true and correct to the best of my knowledge. Signed ~ ZL/ ~r..¢. L. Zz-,~_...,' ~ · // ¢¢..~..[ FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so repreSentative may witness Plug integrity __ BOP Test __ Location clearance ~ Mechanical Integrity Test __ Subsequent form required 10-, oRIGiNAL SIGNED 15. Status of well classification as: Suspended__ Approved CoPY ReturneQ - lApprOvalNO' ¢_..,,~-~' ~ Approved by order of the CommissiOn ~.0blNIE C, SMITH Form 10-403 Rev 06/15/88 Commissioner SUBMIT IN TRIPLICATE Attachment #1 WELL D-11 STIMULATION PROCEDURE 1. R/U LINES AND PUMPING EQUIPMENT. 2. CONDUCT SAFETY MEETING. 3. TEST LINES TO 4000 PSI. 3. PUMP 500 GALS 15% HC1 PICKLE TREATMENT WITH THE FOLLOWING ADDITIVES: 25% XYLENE 0.2% INHIBITOR 20#/1000 GAL ERYTHORBIC ACID 1.5% DISPERSANT DISPLACE TO THE END OF TUBING WITH FIW AT 0.5 - 1.0 BPM. DO NOT ALLOW TUBING PRESSURE TO EXCEED 3500 PSI. 4. PLACE WELL ON GAS LIFT AND PRODUCE BACK SPENT ACID TO CLEAN UP SEPARATOR. NEUTRALIZE ACID AS APPROPRIATE. 5. BLEED CASING PRESSURE TO CLOSE GAS LIFT VALVES. MONITOR CASING PRESSURE WITH A PEN RECORDER. 6. PUMP THE FOLLOWING TREATMENT: A. 1250 GALLONS XYLENE B. 300 GALS NH4C1 FOAMED TO 65 QUALITY. C. REPEAT STEPS A AND B TWO ADDITIONAL TIMES. D. REPEAT STEP A. 7. DISPLACE THE XYLENE TO THE PERFORATIONS WITH 3% NH4CL. 8. ALLOW A 2 HOUR SOAK PERIOD. 9. PUMP THE FOLLOWING TREATMENT: A. 1250 GALS 7.5% HC1 WITH 5% EGMBE 20#/1000 GAL ERYTHORBIC ACID 0.2% A250 INHIBITOR 0.2% F75N SURFACTANT B. 300 GALS 3% NH4C1 FOAMED 65 QUALITY. C. REPEAT STEPS A AND B TWO ADDITIONAL TIMES. D. REPEAT STEP A. 10. DISPLACE THE ACID TO THE PERFORATIONS WITH 3% NH4CL. 11. PLACE WELL ON PRODUCTION. em\docs\dvp~D11 MARATHON OIL COMPANY TRADING BAY UNIT WELL D-ii Completed 03/16/89 ALL measuremen'cs are RKIL 'co 'cop o~ equ~pmen'c. 4E.P' Cameron 'F' Tla0. Hngr. 4.5' ASL Top, X ;lo'cm. 370' O'CI~ 3.5' Series 10 TR SC~V Type FHa( (E.BI3' II)). ComDietlon S'crlng. O'-lO, BE1' 3.5' 9.3#, EUE 8rd, L-80 Ail Mod ilu~'c Tlog. Gas II~'C mandrels are 3.5' CAMCO MMG II (E.867' II)) w/Ag Mod EUE 8rd couplings. Valves ere CAMCO R-EO 1.5' w/RK la'cches. Valve #9 is orl+'lce ~ype. 13-3/8' Csg 61# J-55' @ E511' TDL 7' E 9440' 9-5/8' Csg 40, 43.5, 47# N-80 & RS-95 Csg E 9691' 7' Csg Eg# N-80 @ 11,514' B-L3 Il-4 E477' #1 1E/64' Por~ 4646' #E IE/64' Por'c 6~-14' #3 12/64' Port 7341' #4 16/64' Por'c 7978' #5 16/64' Por~ 8561' #6 16/64' Por'C 9144' #7 16/64' Por'c 975E' #B ~0/64' Por'c 10,359' #9 E0/64' Orifice 10,731' 10,731' 10,745' 10,756' 10,788' IO, BEI' B-l,3 B-4 B-5 B-6 Ilaker Seal Assemialy Loca'cor & seal assembly Baker P]]R w/'CH' Anchor Latch 7' Eg# Ilaker 3H Perm Pkr w/mlllou~ (4.5' EUE Brd Pin x Pin) 4.5' x 3.5' XD (8rd ilox x EUE 8rd) O'cls 'XN' Nipple (E.813' III) w/E.75' NoGo 9ake~ Shearou~ ~ub. Per?orations . 10,90E'-10,985' 6 SPF lEO' Phasing 03/89 10,998'-11,154' 6 · · ll,~P-O'-ll,~50' 6 · · 11,3E0'-11,390' E O' Phasing 10/75 il-5 PBTI) e 11,4E5' TI) e 11,514' Revision I)a'ce, 3/E1/89 Revised Ily, MRO/ne? Reasonm RecoMp[e'clon Previous Revision. 9/87 STATE OF ALASKA ) ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown __ Stimulate__ Plugging __ Pull tubing Alter casing __ Repair well ~ 2. Name of Operator 5. Type of Well: UNOCAL (Marathon Oil Company-Sub-Operator) Development__ Exploratory __ 3. Address ! Stratigraphic __ P.O. Box 190247 Anchorage, AK 9951~) Service-- 4. Location of well at surface Leg A-2, Cond. #3 Do3].y Varden Platform 761' FSL, 1,131' FWL, Sec. 6-8N-13W-SM At top of productive interval 514' FSL, 673' FWL, Sec. 32-9N-13W-SM At effective depth 830' FSL, 786' FWL, Sec. 32-9N-13W-SM At total dep. th 987' FSL, 848' FWL, Sec. 32-9N-13W-SM Perforate Other...~.X Recompl eti0n 6. Datum elevation (DF or KB) 106' KB above MSL 7. Unit or Property name Tv,;~rl'inn R~v IIn-~f 8~ Well-r~u~nl~e~:" ---- D-11 9, Permit number/approval number 8-536 , , 10. APl number 5o-733-20140-01 feet 12. Present well condition summary Total depth: measured true vertical 11. Field/Pool Hemlock Effective depth: measured true vertical Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: 11,682 ' feet Plugs (measured) None 10,021' feet 11,425' feet Junk(measured) None 9,828' feet Length Size Cemented Measured dePth True vertical depth 2,511' 13 3/8" 2,400 sx 2,511' 2,339' 9,691' 9 5/8" 2,600 sx 9,691' 8,452' 2,074' 7" 600 sx 11,514' 9,898' measured Bench 1, 3 10,902' - 10,985' MD 9,428' - 9,493' TVD Bench 4 10,988' - 11,154' MD 9,502' - 9,620' TVD truevertical Bench 5 11,194' - 11,300' MD 9,651' - 9,733' TVD Bench 6 11,320' - 11,390' MD 9,749' - 9,803' TVD Tubing (size, grade, and measured depth) 13. 14. 3.5" 9.3#, EUE 8rd, L-80 AB Mod Butt tbg to 10,821' Packers and SSSV (type and measured depth) - 7" 29# Baker 3H Perm Pkr w/ millout ext @ 10,745', Otis Series 10 TR SCSSV type FMX REE,EI.VED Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure Representative Daily Average Production or Injection Dat~~'~''"'" ........... ~nch~r.age OiI-Bbl Gas-Md Water-Bbl Casing Pressure ~uD~ng Pressure I 389 1050 125 Prior to well operation 2/06/89 103 49 456 1100 130 Subsequent to operation 4/11/89 128 16. Status of well classification as: Oil x Gas__ Suspended Service 15. Attachment~ 1 Copies of Logs and Surveys run __ Daily Report of Well Operations X Date ~'-'~,-~, '~ SUBMIT IN DUPLICATE 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Form 10-404 i~ev 06115188 Attachment #1 Daily Summary of Well Operations Well D-11 01/28/89 01/29/89 01/30/89 01/31/89 02/01/89 02/02/89 02/03/89 02/04/89 02/05/89 02/06/89 02/07/89 02/08/89 02/28/89 03/01/89 03/02/89 ACCEPTED RIG at 1200 hrs. 1/28/89. R/U rig. Having surface freezing problems due sub-zero weather. R/U to finish killing well. Killing well with 3% KC1 water. Circ 3% KC1 and FIW down tubg took returns up annulus. SI. SCSSY and tree. Preparing to shut down due to cold weather. Shut down due to weather. Shut down due to weather. Shut down due to weather. Shut down due to weather. Shut down due to weather. Shut down due to weather. Shut down due to weather. Shut down due to weather. Shut down due to weather. OPERATION SUSPENDED; FINAL REPORT UNTIL OPERATION IS RESUMED. ACCEPTED RIG @ 1800 hrs 2/28/89. Pump 380 bbl 3% KCl down annulus, bleeding gas from tbg. Pressure dropped 700-100 psi. Pump 710 bbl down annulus taking returns @ clean well tank until returns in tbg clean. R/U slick line and pull DKS ball valve. Pump down tbg, had oil in returns. Pump until clean. Monitor well. Tbg dead. Annulus on vaccuum. R/U slick line to run 2.16" gauge ring. Ran 2" gauge ring to 10,702'. Tagged fluid at 540' Perf tbg 10,685'-86'. Pump down annulus taking returns to ciean well tank. Mix and spot 40 bbl HEC pill @ 10,685' Still had lost returns. Pump dye marker to locate additional hJle. Did not see marker. Spot 40 bbl HEC pill @ 10,685'. Fluid loss decreased from 14 bph to 9 bph. Monitor well, losing 10 bph. Mix and spot 80 bbl HEC pill 4960'-3480' in annulus. Fluid loss decreased to 4.bph~~Se~t' ~IT ~~1~ N/D x-mas tree. N/U BOPE. Test BOPE 250/2500 psi 250/1500 psi. Pump down tbg. Press increased to 1000 ~)§~. No. Daily Summary of Well Operations Well D-11 Page 2 returns. Pull hanger free. Attempt to pull PKR f. ree. No success. R/U APRS to run chemical cutter. 03/03/89 RIH and cut tbg @ 10,412' Work pipe free. Pump down tbg to clean well tank. S/D due to high wind 80+ mph. Need to move tbg from west side to east side. 03/04/89 Wait on wind. POOH. L/D 4-1/2" and 3-1/2" completion equipment. TOF @ 10,385'. Change PR's to 5". Test PR's to 250/2500 psi. M/U fishing BHA. RIH. P/U d.p. 03/05/89 RIH w/overshot. Engage fish @ 10,386' DPM. Grapple slipped from fish. POH. Change grapple and add extension. RIH. Engage fish @ 10,386' DPM. Could not jar packer free. R/U to run free point. 03/06/89 Attempt 'to re-engage fish for backoff. Grapple slipping off. POH change grapple, add extension and change oil jars. RIH latch fish. Run freepoint. Pipe free @ 10,684' POH. RIH w/stringshot could not get left hand torque. POH w/stringshot. Make blind backoff. POH recovered 81.44' fish. TOF @ 10,467'. 03/07/89 Redress overshot. RIH. Engage fish @ 10,467'. Fire string shot. Back off at 10,681'. POOH. LD fish (214.79'). MU wash pipe fishing assembly. RIH. Wash over fish from 10,681'-10,810' (GLM 10,712'-10,715'). Circulate hole clean. 03/08/89 CBU. LD washpipe. RIH w/overshot assembly. Engage fish @ 10,681'. Pull free w/40,O00 over. CBU. POOH. Recovered 1 jt tubing (31.20'). TOF @ 10,712'. MU overshot assembly. RIH. Engage fish. Pull free w/60,O00 over. CBU. POOH. 03/09/89 POOH. Recovered all of fish. Test BOP's and choke manifold. RIH. Wash and ream from 10,902'-11,370'. Drilled solid fill 11,370'-11,385'. Wash from 11,385'-11,420'. Drilled solid fill 11,421'-11,425'. CBU. POOH. 03/10/89 POOH. Make 9-5/8" scraper run to 7" liner top at 9440'. Circ. Hi-vis sweep. POOH. RIH and scrape 7" liner from 9440'-11,425'. Displace hole to 3% KC1 & FIW. Filter 3% KC1 FIW. 03/11/89 Filter 3% KC1 FIW through DE filter system. POOH. R/U Schlumberger. Run CET log. R/D Schlumberger. RIH w/7" RBP and 9-5/8" RTTS to TOL. Slip and cut drlg line. RIH. 03/12/89 RIH. Test 7" liner and liner lap to 2000 psi, okay. Test 9-5/8" csg to 2500 psi, okay. POOH. RIH to 11,425'. Filter 3% KC1 FIW w/DE unit. Daily Summary of Well Operations Well D-11 Page 3 03/13/89 Filter 3% KCl fluid. POOH. M/U TCP BHA and RIH. Fill d.p. w/H20 for 1000 psi underbalance. Correlate guns w/ GR/CCl. Set pkr. Perforate bench 1,3 10 902'-10,985';_bench 4 10,998'-11,154'; and bench 5 11,220'-11,250~ w/6 SPF, 120° phasing. No flow in bubble bucket for 10 minutes. Increased to good blow in bottom of bucket. SI for buildup. 03/14/89 Finish BU. Unseat pkr. RO to production. Had 13 bbl influx. Well taking 20 bph. Mix and spot 20 bbl Lite-Sal. POOH 16 stds. Well taking 8 bph. Mix and spot HEC pill. Losing 3-4 bph. POOH. LD perf assembly. RIH w/ 3-1/2" d.p. and 4-3/4" d.c.'s. LD same. RU csg crew. RU and run 3-1/2" completion string. 03/15/89 Finish RIH w/ 3-1/2" completion string. Set pkr at 10,731'. Set BPV. ND BOPE. NU x-mas tree. 03/16/89 Fin NU tree, test to 5000 psi, OK. RELEASE RIG to D-1 @ 0730, March 16, 1989 for slick line work. em\docs\dvp\D11 ,, % /~.LA~,'iI STATE OF ALASKA ~)S OIL AND GAS CONSERVATION COM, SION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon [] Suspend [] Operation Shutdown [] Re-enter suspended well [] Alter casing [] Time extension [] Change approved program [] Plugging [] Stimulate [] Pull tubing ~ 'Amend order [] 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 A-2, Cond. ~/3 Dolly Varden Platforu 761' FSL, 1,131' FWL, Sec. 6-8N-13W-SM At top of productive interval 514' FSL, 673' FWL, Sec. 32-9N-13W-SM At effective depth 830' FSL, 786' FWL, Sec. 32-9N-13W-SM At total depth 987' FSL, 848' FWL, Sec. 32-9N-13W-SM 5. Datum elevation (DF or KB) 106' KB above MSL 6. Unit or Property name Trmd-{n~ RAy TTn'lt 7. We}~ number D-11 8. Permit number 68-73 9. APl number 50-- 733-20140-01 10. Pool Hemlock feet 11. Present well condition summary Total depth: measured true vertical 11,682' feet Plugs (measured) 10,021 ' feet None Effective depth: measured true vertical Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Length 11,425 ' feet Junk (measured) 9,828 ' feet Size Cemented 2,511' 13 3/8" 9,691' 9 5/8" 2,074' 7" measured Bench 1, 3 Bench 4 true vertical Bench 5 Bench 6 Tubing (size, grade and measured depth) None Measured depth True Vertical depth 2,400 sx 2,511' 2,339' 2,600 sx 9,691' 8,452' 600 sx 11,514' 9,898' 10,902' - 10,976' MD 9,428' - 9,486' TVD 11,000' - 11,154' MD 9,502' - 9,620' TVD 11,194' - 11,300' MD 9,651' - 9,733' TVD 11,320' - 11,390' MD 9,749' - 9,803' TVD 4 1/2" N-80 @ 9,312', 3 1/2" N-80 @ 9,312' - 10,820' Packers and SSSV(type and measured depth) Guiberson "RH-i" Packer @ 10,803', Otis "AD" BV @ 341' 12.Attachment~ 1, 2, Description summary of proposal ~ Detailed operations program ~ BOP sketch &3 13. Estimated date for commencing operation August 1988 14. If proposal was verbally approved ~ubsequeat Wor][ 1~~ o~t i;~, .... ~' "... ~ ~) :'~ Form No ........... Dated-./_,7_. Name of approver 15. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ,/~,~/~./~~ ~ Title Environmental Engineer Rq~' U. RODerts ~ Commission Use Only Date 7/6/88 Conditions of approval Notify commission so representative may witness [] Plug integrity [] BOP Test [] Location clearance Approved by ORIGtNAL SIGNED BY LONNIE C. SMITH Approved Copy Returned Commissioner JApproval No. ~m~ j._3~ by order of the commission Date Form 10-403 Rev 124-85 Submit in triplicate Attachment #1 Well D-II Procedure 1. The tubing annulus will be filled with FIW prior to moving the rig over Well D-il. 2. Check to make sure well is dead. Set BPV. NU and test BOPE. Pull BPV. 3. Pull RH-1 retrievable packer free and CBU. 4. POH and LD 4-1/2" x 3-1/2" completion string. 5. RIH w/bit and csg. scraper. POH. 6. RIH w/6" bit and clean out fill and scale to PBTD @ 11,425' MD. 7. RU WL and run csg. inspection log. 8. Pressure test liner lap. 9. RIH and reperforate selected Hemlock intervals with TCP guns. POH. 10. RIH with perm packer and set @ ±10,780' MD. 11. RIH with redesigned gas lift system. 12. ND BOPE. NU and test X-mas tree. 13. Unload well and turn over to production. Note: Anticipated maximum bottomhole pressure is 3700 psi. Completion fluid will be FIW sufficiently weighted to keep the well overbalanced. ?EM/em/40/Sundr3 - RECEIVED .I~L - 8 1988 Alaska Oit & Gas Cons. Commission Anchorage Attachment #2 'TBU HELL D-11" · *.-(~rrent Completion) TBU Well D-Il (Proposed Completion) 2.125' I0 of Valve 3.813' i~ of llipplt 4Ti' 12.6f ri-CO St. Tubing -- 9-5/8' 40, 43.S, 471 N-80 Cas h,g 3~' g.3! 11-80 SL Tubing 9691 *..--..e- 291 x-Line Liner ' ; #otc: Perforation intervals are OIL measurements *~. .. . .. . · · 3351' 4760' S807' Gt.Y 7152' Gt.V 7615° Gt.V 8rOI' GLV 8572' GLY 8906' GLY .9274'GLy 9312' 9620° 9993' .~-.-10,362' -(----i0,704' GLV I 4'~USi C2F flandrels w/Guiberson GLV 2 Valves 4.00" 12 3 4 -. G 7 8 IO 4!i' x 3~' X-Over SLV 11 3'~' U~l C2F ~tand~l w/Guiberson GLV 12 Valves 3.00' lO GLV 13 GLY 14 blocked aaprox. 10,720'(11/87) 10,769' 10,803' - Gulberson 7' 28-321 x 3~' ~l-! Pacla 2.99~' lO ~ !0,818~ Otis 'Q' Hlpple 2.625' [D l~,g02~u 10,820' Bottom of Tailpipe B-I ,.3.. · 11,000' 8-4 11,164' !1,194' B-S 11,300' _ 11,390' FII1 ~11,375"U.. an 7/82 · , PBT0 8 11,425' "0 10 e 11,51~' R£CrclV J!IL - 8 19~ AlasT~ 0ii & Gas Cons. Anchorage ,. . · Revised 9/87 Otis Ball Valve SSSV 3-1/2" Tog String 9440, _ 11,514' 7", 29J l-Line Liner 9691' - 9-5/8", 40~, &3.SJ, 471 N-80 Cs8 10,780' Perm Packer PerforaCions__~OZL) B-I 10,902' - 10,976' B-4 I1,000' - ll,15&' B-5 11,19~' - 11,300' B-6 11,320' - 11,390' 11,t25' PBTD 11,514' TD - MARATHON OIL GO.-- -- DOLLY VARDEN PLATFORM -- Attachment #3 - MM Pon ~ Flowlin¢ D~iilin~t Nippi~ P r-~..~e..rd-e.r. (Pipe. -,,' ~ ~.Bil'hd Ramg) ',, "": ~ -5,000 -Kill Lin~, -- Chok~ Lin~- ~ ~ CIW Swin~' Bolt Clamp --Dia r~me 2 - 13S/s"x 5,000 _.~ , ....... [~ ~, ,..~-.---- Drillin 'From Uhd~r 1~/6'' _ · ' ~e ' - JIlL 81988 - - '. I ! n . Alask~ 0il & Bas ~n~. Commission ' · t~I I ~l Anchomge . .: ~~F~. Spool~ · ,~l lo '~ . -- Well Room Floor Collar I$ :Ye,' Surface C~onductor APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon [] Suspend [] Operation Shutdown ~ Re-enter suspended well [] Alter casing [] Time extension [] Change approved program ~ Plugging [] Stimulate ~ Pull tubing ~ Amend order [] 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 A-2, Cond. #3 Dolly Varden Platfor~ 761' FSL, 1,131' FWL, Sec. 6-8N-13W-SM At top of productive interval 514' FSL, 673' FWL, Sec. 32-9N-13W-SM At effective depth 830' FSL, 786' FWL, Sec. 32-9N-13W-SM At total depth 987' FSL, 848' FWL, Sec. 32-9N-13W-SM 5. Datum elevation (DF or KB) 106' KB above M:~., 6. Unit or Property name Trmr14~nC Ray llntt 7. Well number D-11 8. Permit number 68-73 9. APl number 50-- 733-20140-01 10. Pool Hemlock feet 11. Present well condition summary Total depth: measured true vertical 11,682' feet Plugs (measured) None 10,021' feet Effective depth: measured 11,425 ' feet Junk (measured) None true vertical 9,828 ' feet Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Length Size Cem::nted Measured depth. True Vertical depth 2,511' 13 3/8" 2,400 sx 2,511' 2,339' 9,691' 9 5/8" 2,600 sx 9,691' 8,452' 2,074' 7" 600 sx 11,514' 9,898' measured Bench 1, 3 10,902' - 10,976' MD 9,428' - 9,486' TVD Bench 4 11,000' - 11,154' MD 9,502' - 9,620' TVD true vertical Bench 5 11,194' - 11,300' MD 9,651' - 9,733' TVD Bench 6 11,320' - 11,390' MD 9,749' - 9,803' TVD Tubing (size, grade and measured depth) 4 1/2" N-80 @ 9,312', 3 1/2" N-80 @ 9 312' - 10 820' Packers and SSSV (type and measured depth) ' ' Guiberson "RH-i" Packer @ 10,803', Otis "AO" BV @ 341' 12.Attachment~: 1, 2, Description summaryof proposal ~ Detailed operations, pr~gl.~r~. ,Pop, sketch & 3 F[ b I V b-U 13. Estimated date for commencing operation August 1988 Iiii _ I:l 1noel 14. If proposal was verbally ap~[~J~uent; ~vVoz~ 1Reporlecl on Form No. Dated__/__/__ Name of approver Alaska Oil & Gas Cons. Commission Dat~j~l'~(~d 15. I hereby certify that the foregoing is true and correct to the best of my knowledge S,gned ' R~,' LT.' RoOerts ' O~'-m, Title Environmental Engineer Date 7/6/88 Commission Use Only C:, .ditions of approval Notify commission so representative may witness [] Plug integrity [] BOP Test [] Location clearance Approved by ORIGINAL SIGNED BY LONNIE C. SMITH Approved Copy Returned ?' Commissioner J Approval NO. (~""- '~'~ 6" by order of the commission Date'S,_ Form 10-403 Rev 12-1-85 Submit in triplicate Attachment #1 Well D-ii Procedure 1. The tubing annulus will be filled with FIW prior to moving the rig over Well D-il. 2. Check to make sure well is dead. Set BPV. NU and test BOPE. Pull BPV. 3. Pull RH-1 retrievable packer free and CBU. 4. POH and LD 4-1/2" x 3-1/2" completion string. 5. RIH w/bit and csg. scraper. POH. 6. RIH w/6" bit and clean out fill ahd scale to PBTD @ 11,425' MD. 7. RU WL and run csg. inspection log. 8. Pressure test liner lap. 9. RIH and reperforate selected Hemlock intervals with TCP guns. POH. 10. RIH with perm packer and set @ ±10,780' MD. 11. RIH with redesigned gas lift system. 12. ~ BOPE~ NU and test X-mas tree. 13. Unload well and turn over to production. Note: Anticipated maximum bottomhole pressure is 3700 psi. Completion fluid will be FIW sufficiently weighted to keep the well overbalanced. PEM/em/40/Sundr3 RECEIVED JIlL .- 8 1988 Alaska ,Oil & I~as Cons. Cor~ission Anchorage Attachment f/2 4~1' 1Z.6~ II-I~O SL Tubing 40, 43.5, 47f Casing 9.3! M-8O SL lubing 9&&O · ~ ~691 ~ 291 x-Line Liner · 'TBU WELL D-11" --. (Current ComplerjLon) ~ ~34i'r'o~l~'F~ael AO 4k' Ball ';41v& 2,125' ID of Valve 3.813' ID of ~lipple 3351' 4760' 5807' 6596' 7152' 7515' 8101' 857Z' 8906' g27~' 9312' 9620' 9993' ,,~,---10,362' '~""---10,70~* SLY I 4's*USI C2F Ilae(relS w/Guiberson i.t-ll GLY Z Valves 4.00' 13 SLY 3 SL~ 4 .. GLY ~ GLV 6 GLY ? GLY 8 , GLY g GLy lO 4~1' x 3'z* X-Over 6LV 11 3'~' USI CZF ;landrel w/Gulber$on GLV 1~ Valves 3.00' 10 GLV 13 GLY 14 blocked aaprox. 10,769' US[ Circulatlw SleeYe 10,803' '*'-'-" Guiberson 7' 28-321 x 3~' ~1-1P~Cb~ 2.99Z' lO ~ 10,618' Otis 'q' fllpple 2.625' iD ~- lO,B20' Bottom of Tallpipe : 10,90Z' B-l,3.,. ** * 11.000' B-4 11,194' B-5 - 8-6 11,390' ~.. ~ PgTO g 11,4~5' ..____. lO tg I1,S1,~" flote: Perforation Intervals are DIL measurements Revised 9/87 .. W£C R£C Jt.IL Ai~s~ Oil ,& TBU Well D-Il (Proposed Completion) Otis Ball Valve SSSV 3-1/2" Tbg String 9&&O, _ 11,'51~' 7", 29~ X-Line Liner 9691' - 9-5/8", &0#, 43.5~, ~7~ N-80 Cs8 10,780' Perm Packer Perforation$__~I__L) B-! 10,902' - 10,976' a-4 11,000' - 11,151' ;ion B-5 11,194' - 11,300' B-6 11,320' - 11,390' 11,~25' PBTD 11,514' TD - MARATHON OIL GO.- Attachment ¥~3 ~ Mu<l Do. / F'iowlin¢ . Dr-jill nc~ llil::,p i-~. DOLLY VARDEK! PLAT FORN -- U (Pipe ~ ~CIW Swin~- Bolt Clamp - ~~~ ~- ,~'/~"~ s, oo0' r'o o, RECEIVED Riser ~ BOP Slack For ~o Drilling~ From Uhdcr l~s/s" JUL - 8 ]988 ~urface Oasin9 To Z D.-- Al~sk~ 0~1 & Gas 00.s. C0mmissi0. , ~chorage We.il Room Floo~ 'x 13 ~/~' Surfo, c.c Oasir,,..q C, onduc.-~or ALAS -)OIL ANDSTATE OF ALASKA GAS CONSERVATION COM ~JSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown [] Alter Casing [] Other [] 2. Name of Opera~tor UNOCAL 3. Address Stimulate [] Plugging [] Perforate [] Pull tubing [] 5. Datum elevation (DF or KB) 106' KB above MSL 6. Unit or Property name P.O. Box 190247 Anchorage, AK 4. Location of well at surfaceLeg A-2, Cond. If3 Dolly Varden Platform 761' FSL, 1,131' lrWL, Sec. 6-SN-I3W-SM At top of productive interval 514' FSL, 673' FWL, Sec. 32-9N-13W-SM At effective depth 830' FSL, 786' FWL, Sec. 32-9N-13W-SM At total depth 987' FSL, 848' FWL, Sec. 32-9N-13W-SM 11. Present well condition summary Total depth: measured true vertical 11,682' feet Plugs (measured) I0,021 ' feet T,radtn~ Bay Unit 7. Well number D-il 8. Approval number 533 9. APl number 50-- 733-20140-01 Feet 2,339' 8,452' 9,898' D a t e /'2'-/~"~/~ Submit in' Duplicate 10. Pool Hemlock 11,425' - 11,513' - cmt Effective depth: measured 11,425 ' true vertical 9,828' feet Junk (measured) feet None Casing Length Size Structural Conductor Surface 2,511' 13 3/8" Intermediate Production 9,691' 9 5/8" Liner 2,074' 7" Perforation depth: measured Bench 1 Bench 4 Bench 5 Bench 6 true vertical Cemented 2,400 sx 2,600 sx 600 sx 10,902' - 10,976' MD 11,000' - 11,154' MD 11,194' - 11,300' MD 11,320' - 11,390.' MD Tubing (size, grade and measured depth) 4 1/2" N-80 @ 9,312', 3 1/2" N-80 @ 9,312' - 10,820' Packers and SSSV (type and measureddepth) Guiberson "RH-i" Packer @ 10,803', Otis "AC" BV @ 341' Measured depth 2,511' 9,691' 11,514' 9,428' - 9,486' TVD 9,502' - 9,620' TVD 9,651' - 9,733' TVD 9,749' - 9,803' TVD True Vertical depth 12. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Prior to well operation 11/4/86 408 131 541 1125 psig Subsequent to operation 11/17/86 385 123 453 1130 psig Tubing Pressure 130 psig 130 psig 14. Attachment~ ell Daily Report of Well Operations [] Copies of Logs and Surveys Run [] 15. I hereby certify that the foregoing is true and correct to the best of my knowledge ~ / ~'"'~'~ -~-~ * M_arathon~Oil Cpmpany- Sub Operator Signed Roy/ D. Roberts Title Environmental Enqineer Form 10-404 Rev. 12-1-85 ATTACHMENT ~ 1 Daily Report of Well Operations Well D-ii 11/11/86 1. RU coiled tbg unit and pressure tested to 4,000 psi. 2. RIH w/jetting tool and tagged @ 10,720' CTM. 3. Jetted and worked @ 10,720'. Unable to work deeper. 4. POH w/coiled tbg. 11/12/86 1. RIH w/2-3/8" Navi drill on coiled tbg. 2. Tagged @ 10,724' CTM. 3. Attempted to drill @ 10,724' without success. 4. POH w/coiled tbg. 5. RD coiled tbg Unit. 11/13/86 1. RU wireline unit. 2. RIH w/2.625" impression block. Couldn't get deeper than 10,692' WLM. 3. RD wireline unit. 4. Returned well to production. MDC/em/40A/Sundry STATE Of ALASKA APPLICAIION FOR SUNDRY APPROVALS 1. Type of Request: Abandon [] Suspend [] Operation Shutdown [] Re-enter suspended well -~ Alter casing [] Time extension [] Change approved program [] Plugging [] Stimulate [] Pull tubing [] Amend order r- Perforate [] Other 2. Name of Opera. z. tor UNOCAL 3. Address P.O. Box 190247 Anchorage, AK 99519 4. Location of well at surfaceLeg A-2, Cond. #3 Dolly Varden Platform 761' FSL, 1,131' FWL, Sec. 6-8N-13W-SM At top of productive interval 514' FSL, 673' FWL, Sec. 32-9N-13W-SM At effective depth 830' FSL, 786' FWL, Sec. 32-gN-13W-SM At total depth 987' FSL, 848' FWL, Sec. 32-9N-13W-SM 5. Datum elevation (DF or KB) 106' KB above MSL 6. Unit or Property name Trading Bay Unit 7. Well number D-11 8. Permitnumber 68-73 9. APInumber 50-- 733-20140-01 10. Pool Hemlock 11. Present well condition summary Total depth: measured true vertical 11,682' feet Plugs (measured) 10,021 ' feet None Effective depth: measured 11,425 ' true vertical 9,828 ' feet Junk (measured) feet None Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Length Size 2,511' 13 3/8" 9,691' 9 5/8" 2,074' 7" measured Bench 1 Bench 4 true vertical Bench 5 Bench 6 Tubing (size, grade and measured depth) Cemented 2,400 sx 2,600 sx 600 sx 10,902' - 10,976' MD 11,000' - 11,154' MD 11,194' - 11,300' MD 11,320' - 11,390' MD P .4 1/2" N-80 @ 9 312', 3 1/2" N-80 @ 9,312' acKers and SSSV(type ~nd measureddepth) Guiberson "RH-i" Packer @ 10,803' - 10,820' , Otis "AO" BV @ 341' Measured depth feet 2,511' True Vertical depth 9,691' 11,514' 2,339' 8,452' 9,898' 12.Attachments 9,428' - 9,486' TVD' 9,502' - 9,620' TVD 9,651' - 9,733' TVD 9,749' - 9,803' TVD Description summary of'-proposal ~ Detailed operations program [] BOP sketch [] October 1986 13. Estimated date for commencing operation U UI C, · J~OU Date approve~I~CI Oil & Gas Co~. Comfl 14. If proposal was verbally approved Name of approver 15. I hereby certify that the foregoing is true and correct to the best of my knowledge Signedd7 ~. ~~ Title ~.~.~/~/.~ f; Commission Use Only Conditions of approval commission so representative may witness I Approval No. [] Plug integrity [] BOP Test [] Location clearance I * Marat~~'~~~or Approved by ~ '// -k,._., ~~/~ Form 10-403 Rev 12-1-85 I / ' ~provea Cooy = by order of ~/~~~. Commissioner the commission Dat ~ub~mit il triplicate ATTACHMENT PROCEDURE TBU WEll D-ii Scale and Fill Cleanout It is Marathon's intention to remove tubing scale restrictions and clean out fill using coiled tubing on Well D-11 during October 1986 by the following procedure: 1) Rig up and pressure test coiled tubing and connections. 2) Run in hole with jet tool using 1 1/4" coiled tubing. 3) Jet through tubing tail at 10,820', circulate clean. 4) Clean out to PBTD, 10,425'. Circulate clean. 5) Pull out of hole with coiled tubing and rig down. 6) Return Well D-11 to production. MDC/em/40/Sundry Union Oil and Gas Divi.sion: Western Region Union Oil Company u~ ~alifornia P.O. Box 6247, Anchorage, Alaska 99502 Telephone: (907) 276-7600 unlen Nay 6, 1985 Mr. Chat Chatterton Alaska Oil and Gas Conservation Comm. 3001 Porcupine Drive Anchorage, Alaska 99501 SUNDRY NOTICE'S Dear Mr. Chatterton: Attached for your approval is a Sundry Notice of intention for K-3RD, and Subsequent's for D-11 & D-29, Trading Bay Unit. Please return the approved Sundry Notice to the undersigned. LOC/tj Attachments Very truly yours, Lawrenc~O. Cutting ENVlRONNENTAL SPECIALIST STATE OF ALASKA ALASKA AND GAS CONSERVATION ISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL OTHER [] 2. Name of Operator 7. Permit No. Union Oil Company of California* 68-73 3. Address 8. APl Number P.O. Box 6247 Anchorage, AK 99502 50- 733-20140 4. Location of Well Surface: Leg A-2, Cond. #3, Dolly Varden Platform 761' FSL, 1131' FWL, Sec. 6-8N-13W-SM 5. Elevation in feet (indicate KB, DF, etc.) 106 ' KB above MSL 6. Lease Designation and Serial No. ADL- 175 94 9, Unit or Lease Name Trading Bay Unit 10. Well Number D-11 11. Field and Pool McArthur River Field 12. (Submit in Triplicate) Perforate [] Alter Casing [] Perforations Stimulate [] Abandon [] Stimulation Repair Well [] Change Plans [] Repairs Made Pull Tubing [] Other [] Pulling Tubing (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Duplicate) [] Altering Casing [] Abandonment Other 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). TBU WELL D-11 SCALE CLEANOUT Coiled tubing scale cleanout operations were canceled after several attempts to pull the ball valve at 341' were unsuccessful. *Marathon Oil Company, Sub Operator RECEIVED AYo ? 985 Alaska Oil & ~as Cons. Commission Anchorage 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed Lawrg'~ce O. Rut.+f ~.g ¢'~,~ Title ENV I RONMFNTAL The space below for Commission use SPE~!AL! ST Conditions of Approval, if any: By Order of Approved by COMMISSIONER the Commission Date Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate Union Oil and Gas ')sion: Western Region Union Oil Company of California P.O. Box 6247, Anchorage, Alaska 99502 Telephone; (907) 276-7600 union ~ebruary 14, 1985 Mr. C.V. Chatterton Ak. 0il and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK. 99502 Dear Mr. Chatterton: SUNDRY NOTICES D-17RD, D,tl,D-8RD Attached please find Sundry Notice Intentions for the following wells. D-17RD, D-11, & D-8RD all Trading 8ay Unit, McArthur River Field. Please return the approved Sundry Notice's to the undersigned. Very truly yours, Lawrence O. Cutting ENVIRONMENTAL SPECIALIST. LOC/ti Attachments RECEIVED FEB 2 1 1985 Alaska Oil & Gas Cons. commission Anchorage ,f STATE OF ALASKA ALASKA ,Z AND GAS CONSERVATION CO ISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL OTHER [] 2. Name of Operator 7. Permit No. Union Oil Company of California* 68-73 3. Address 8. APl Number P.O. Box 6247 Anchorage, AK 99502 50- 733-20140 4. Location of Well Surface: Leg A-2, Cond. #3, Dolly Varden Platform 761 ' FSL, 1131 ' FWL, Sec. 6-UN-13W-SM 5. Elevation in feet (indicate KB, DF, etc.) 106 ' KB above MSL 6. Lease DesignatiOn and Serial No. ADL-17594 9. Unit or Lease Name Trading Bay Unit 10. Well Number D-11 11. Field and Pool McArthur River Field 12. Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: (Submit in Triplicate) Perforate [] Alter Casing [] Perforations Stimulate [] Abandon [] Stimulation Repair Well [] Change Plans [] Repairs Made Pull Tubing [] Other [] Pulling Tubing (Note: Report multiple completions on Form 10-407 with a submitted Form 10~407 for each completion.) SUBSEQUENT REPORT OF: (Submit in Duplicate) [] Altering Casing [] [] Abandonment [] [] Other [] 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). TBU WELL D-11 SCALE CLEANOUT It is Marathon's intention to use a coiled tubing unit to clean out scale beginning in February, 1985, as follows: 1. Rig up coiled tubing unit, lines and BOPE. Pressure test to 5000 psi. 2. RIH w/ 2.7" mill on coiled tubing to 10,650' and circulate clean with FIW. 3. Mill out scale through tubing tail at 10,820'. Circulate clean. 4. RIH and tag fill. 5. POH, return well to production. RECEIVED FEB 2 1 1985 *Marathon Oil Company, Sub Operator Signed Lawrence O. Cut+ i no /__.¢~/-"/ Title Fnv i r-(~pmenta ! The space below for Commission use Alaska Oil & Gas Cons. Commission . Anchorage Specialist Date 02- ! 4-85 Conditions of APproval, if any: ~lqaprove~ C ~: ~.-, ltetu~rned ' '. B! L0tt~![ 1:. S~ITII By Order of Approved by COMMISSIONER the Commission Date Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate Form 10-403 REV. 1-10~73 Submit "1 ntentions" in Triplicate & "Subsequent Reports,' in DuPlicate STATE OF ALASKA OI L AND GAS CONSERVATION COMMITTEE SUNDRY NOTICES AND REPORTS ON WELLS (Do not use this form for proposals to drill or to deepen Use "APPLICATION FOR PERMIT--" for such proposals.) WELLL.J OTHER 2. NAME OF OPERATOR Union Oil Company of California * 3. ADDRESS OF OPERATOR 909 W. 9th Avenue, Anchorage, Alaska 99501 4. LOCATION OF WELL At Surface 761.3'N, 1131.5'E Sec. 6, T8N, R13W, from SW corner SM 13- ELEVATIONS (Show whether DF, RT, GR, etc.) RKB 106 ' 14. r5~ APl NUMERICAL CODE 50-133-2014.0 6. LEASE DESIGNATION AND SERIAL NO. ADL 17594 7. IF INDIAN, ALLOTTEE OR TRIBE NAME 8. UNIT, FARM OR LEASE NAME Trading Bay Unit 9. WELL NO. D-11 (14-32} 10. FIELD.AND POOL, OR WILDCAT McArthur River Hemlock 11. SEC., T., R., M., (BOTTOM HOLE OBJECTIVE) Sec. 32, T9N, R13W, SM 12. PERMIT NO. CheCk Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: TEST WATER SHUT-OFF [.__..J PULL OR ALTER CASING FRACTU RE m REAT MULTI PLE COMPLETE SHOOT OR AClDIZE ABANDON* REPAIR WELL CHANGE PLANS (Other) SUBSEG~UENT REPORT OF: WATER SHUT-OFF FRACTURE TREATMENT SHOOTING OR ACIDIZING (Other) REPAIRING WELL ALTERING CASING ABANDONMENT* (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 any proposed work. 11-0675 - 11-08-75 Re-perforate Hemlock Zone as follows' 10,902 - 10,970 (68') 2 HPF 2"1/8" Carrier Gun 11,000 - 11,060 (60') 2 HPF 2-1/8" Carrier Gun 11,074 - 11,154 (80') 2 HPF 2-1/8" Carrier Gun 11,210 - 11,240 (30') 2 HPF 2-1/8" Carrier Gun 11,252 - 11,300 (48') 2 HPF 2-1/8" Carrier Gun 11,320 - 11,350 (30') 2 HPF 2-1/8" Carrier Gun 11,350 - 11,363 .(18') 2 HPF 2-1/8" Carrier Gun (31'3"4'.) MMCF MMCF Prod. Test BOPD BWPD WC LIFT SEP CSG TBG Before Re-perf. 1663 17 1.0% 2.6 2.6 1050psi 130p$i'. After Re-perf. 2097 63 2.9% 2.2 2.2 1050psi 150psi 16. I hereb ~h~t._hefo~~aanclcorrect....~. S,GNE~.~~~~[~L~~~~T,TLE Dist. Drlg. Supt. DATE 1/21/?§ (This for State office use) APPROVED BY. CONDITIONS OF APPROVAL, IF ANY: TITLE Marathon 0il Company Sub - Operator See Instructions On Reverse Side DATE . union January 20, 1976 Mr. Hoyle Hamilton Division of Oil & Gas State of Alaska 3001 Porcupine Drive Anchorage, Alaska 99502 Union Oil and Gas D"~"~ion:. Western Region Union Oil Company ot ~alifornia P.O. Box 6247, Anchorage, Alaska 99502 Telephone: (907) 279-7681 RE: TBUS D-7 (14-33) TBUS D-9 (42-7) TBUs D'11.~(14-32) TBUS D-25 (11-8) DOLLY VARDEN PLATFORM Dear Mr. Hamilton: Enclosed for your approval and in triplicate are the SUndry Notices & Reports on Wells (Form 10-403) for each of the above captioned workovers. Very truly yours, Ji~mR, Callender District Drlg, Supt. sk CC: Marathon Oil Co. Atlantic Richfield Co. Amoco Production Co. Standard Oil Co. Skelly Oil Co. Phillips Petroleum Co. Mr. Rodney Smith-USGS 2 1976 Form P--3 E_EV. 9-30-69 STATE OF ALASKA Submit "Intentions" in Triplicate & "Subsequent Reports" in Duplicate OIL AND GAS CONSERVATION COMMITTEE SUNDRY NOTICES AND REPORTS ON WELLS (Do not use this form for proposals to drill or to deepen Use "APP-LICATION 'FOR [~'Et~i']~'-L~' 'for such 'pi:o~osal-~J · . WELL WELL OTHER 2. NAME OF OPERATOR Union 0il Company of California 3. ADDRESS OF OPERATOR 909 West 9th Avenue, Anchorage, Alaska 99510 4. LOCATION O'F WF-J~L Atsur~ace Northwest leg conductor#3 761.5'N, 1151.5'E, Southwest corner, Section 6' TSN, R15W, S. M. 13. ELEVATIONS (Show whether DF, RT, OR, etc. DF 106-MSL ~. APl NLr~C;~L CODE 50-133-20140 6. LEASI~ DESIGNATION A/VD SERIAL NO. Al)I,- 17594 ?. IF INDIgeN, ALLO'i-i'~'.E OR TRIBE NAAIE 8. UNIT, F~t{M OR LEASE NAME TradSng Bay lJnit 9. WELL NO. D-ii (14-32) 10. FIELD A~D POOL, OR WILDCAT McArthur River - Hemlock 11. SEC,, T., R., M., (BOTTOM HOLE OBJECTIVE) Section 32' T9N, R13W, S. M.. 12. PE~qlVLIT 1~0. Check Appropriate Box To I,nd:i,cate Niat'ure of' N~fic'e, Re, ~ort, or Other D~ta ' NOTICE OF INTENTION TO: ' TEST WATER SHUT-OFF PULL OR ALTER CASING FRACTURE TREAT MULTIPLE COMPI,ETE SHOOT ~ ABANDONs REPAIR WELL CHANGE PLAN~i ~Other) { ., SUBSEQUENT RBPORT OF : WATER SHUT-OFF REPAIRING WELL __ FRACTURE TREATMENT ALTERING CASING SHOOTING OR ACXDIZINO t-- ABANDONMENT' (Other) (NOTE: Report results of multiple completion on Well Completion or Reeompletion Report and Log form.) 15. DESCRIBE I'nOPOSED OR COMPLETED OPERATIONS (Clearly state all pertinent details, and give pertinent dates, including estimated date of starting an}' proposed work. 1. Rig up wireline unit and lubricator, hydrotest lubricator and pull ball valve. 2. With well lifting reperforate Hemlock through tubing at two holes per foot as follows' 60 holes from 10,945' - 10,975' 280 holes from 11,000' - 11,140' 100 holes from 11,220' - 11,270' 3. Install ball valve. 4. Rig down lubricator and wireline unit. 5. Return well to production. FEB ' {'" CJL AND GAS .:.iL.,,, ,.. ANCHORA GE Marathon 0il Company- Sub-Operator 16. I hereby cer~F~that th~ for~in~ true and correct /'/ Jim R. C~ll~.nd~.r/ 2/8/73 CONDXTXONB OF aPPROYAL, XF AR%f :~'~ DATE See Instructions On Reverse Side Approved Copy Returned _ Form STATE OF ALASKA .... OIL AND GAS CONSERVATION WELL cOMPLETION OR R.ECOMPLI~TION REP~T~,~ND LOG * la. TYPE OF WELL: b. TYPE OF COMPLETION: N~.w ~ WOnK ~-~ WELL OVER ~'~2 , ;~ ~, { See other in- 2. NAME OF OPERATO~ COm .... :~ Union Oil ,. pany of Californ.ia* -~ _,~.q~-~.~ 3. ~I~DRESS OF O~ERATOa . ~I ~ 7kli c~ 2805 .Denali stree~,r:::Ancb0r~ge~ Alaska 9950~ r- ~ ..... ,01~~ ~. ~o.o~; o. w~r ~. ~X~lO.'Or ~SL~CReport' locatiO, cliar)~'and"i. ~Ccorda~e wi~h a,~tate ~q~re~e. ts ) * ~McArthur Ri ver ~t ~ ~. ~ ~o~-a.~o. '50~' FS~ & ~77' F~L, S~.3~T~N,R]3~,SH J ~,' ': ........... A~' i~tal d~p~ 80'3'~ FSL, &:',78:3": FWL."~Sec, .:32, T9N. R.I~;][SM ! ~.' 8-31-68. · J,:. 1.0~8-68 ::: J: .1'0-14r68 '].~- ~KB 106 18 T~ D~H ~ & TVD~9.. PLUG; ~6~ MD & ~D~ ~ ~LT~LE C~, J 21. i~TER%ALS ~RiLLED BY 11,68 "D lO,021TVDI11,425MD,"9,8 8TVDJ; J 0-11 682' " p: I ~.~ Bemlock To 0,~01 MB, 9,42.. TVD.' ~.. = · ~ ~= o Yes - Bottom: 11',400 MD,i 9,809 TVD o m DIL,:Borehole Compe'nsa~ed SOnic, Foma~tion Densi ~ pmeter, Cement~ d Ga~a Correlat on ~ '~ mm' ~ ~ m~ ~ ' - ...... CAS~G RECO~ (Re~ all ~tri~s set " ' ' ~ 13:3/ ~ sacks 2600 sacks 28. PE~O~TIONS OPEN TO PRO~U~ON (interv~i, size ~d number) 29. ACID, S~IOT, F~CT'U~, C'~NT SQUEEZE, ~C. 10,902 ~ 10,976":: 11,194- ~1,300' ~ ~' ~'''~ .1 11,000- 11,~54' 11,~0- 11,390' o°" c,~" :'~o = i , .- ~j-.~ .._ J'.~, , ,,, DkTE FIRST P~ODUC~QN ~ ~ODUCTION ~ETHqD (Flowing, $gsilif. t, pqmp~--size a~ ~D~ ~D) JWELL STA~S (~od~e~ o~ Well d~d not flo~ upon completion, w~ng on ~mp~ss~ fo~ g~s l~t~-~ Shut-in FLOW. ~BING' m~a ~S~ JC~~ OI~BBL. GA~. ~ W~B~. JO~ GRAV~Y-~ (C~.) I 'K l '- 1 31. DISPOSITION Or GAS (~0/md, USed fOr ]uel, vented, etc.) ::/t--- ' ':' C:.' ITZST WtTNZSSZD ".2 .... ~ng'~and attached information is complete ~d co~ct as de,trained from all:available records 33. I ~ereby cert~./~t"t~ ... ~ * · ~a~atho. Oil ~ompn.~, Subope~ato~ Dol]~ ~a~den .~- :2 L~ structions on 15.:API NUlVLERICAL CODE ~ ~id~,I 50.1133_20140 ,,J i~DL~17594 :T'rad~ing Bay Unit ' :!D-l) (14-32) -- INSTRUCTIONS · ~:~Gerf~'ral: This form is designed f~Sr sub,.~itting a comPl~te ~'r~d correct: well co":.mpteti6~ repor~ end log on ~all tY'~es of I~nds end leases ~n Alaska. o '.. ._ ~'~ ~... '~ . . ;':'lt,~~ 16: Indicate which elevotion is used a~zreferen'ce (where not o~herwise:~hown) for depth:: measure- ...me~s giy~n in ~ther sp~ces on th~s form ~nd in ~ny ~tt~chments. :'~ ..... ' ~ltem~ 22:: If this well iS;:com~[e~'~d fo[ seporato pp.duction from mo're than-, one interval zone ~(mu[[iple.~omple'tion), so sra~e in' item 20, aqd in i~e~ 2?..,~show the~prcdv~?~ng_ inf'erval, or: -.. intervals, >:~op(~}, bm}om(s):~hd name .~[)(i[~ny[!oi:onl~:~the interval '¢ported i; item 3?. Submit 0 sepo~ete report ,~:~(page~'oh~ithis foil, adequately~Fdent[fie.d, fo[}'~each additiOnal inte~ val to be"s:eperately produ~, show- ,.--~in~ :.~he ~itional data perfine~.*o ~Och'J. in/~'~val. .,. _ -:~ n ~ ¢' ~.:~ .':: ~-.~. ~ ..... Zl**~'~': ?~ac~ C~ment': A,ache~ s0~.i~men.~al records for. this welFshould sho~:~h~ details o~any mul- ~t~ple:~s. tage cementing and the Io&tion" of: the.:gement:~ng tool:.. · :~lt,~28:'~Submit ':~ separate comp~etio~ r~rtbn this form for each 'interval to ~.~parately.,:Produ~. items 20 and:22~.above). ~- .... ~ (~lnst~ction fg.r · .. -, t - "" ': '] ........ ~ L ~ . ', , · · ::> . .. - ._: ~,-- /[JiRY OP I~O~VIATION q~F-,qTS [NCI~DDINCl ]NT~I:I. VAL<~TF-~iTED, P~R~ DA~A ~ ~OV~ OF OIL.' ~. .. '~: ¢ -' .. ' ~.> .~ - .: 35. G~GIC :[..' .y ~- 'WA~ AND MUD .-- ... 1 Liner Lap~Test' ~' " ~ ~,~s. o~ . ,' ~.j . , O' fresh water cu~hionr]set packer at 9420'. ~.~h 5']~:-tail:; opened Top of MGS Ira. 5,128' 4,.:'~504, . es, weak blow for 50.,bi:~tes and died. Recovered 20' mud with :.: " shion; charts ind:i~cat~d 'tool open with no plU~ging. Top of Heml6ck 10,901' 9,4~25' ...... '..-: . . ..; ~:r, ~;... .--. ~. -, :~F .' ,_" _ ..... ~ .... ;" Top of ~est ore- ~09 ..... ~- , - ~,. ...... . ..... 1 and Ira. ?_. 11,400' . ' ~ $, . ../ ,'i. . . .. . ~,E DATA, A'~ACI~T;BRIE~-'. D~CRI~ONS 0P LITttOLOGY, POROSITY, ~AC~R~, APP~NT DIP~ ., .... -' .,:r ~' , /2~. o~,CT~,,., ~oW~. o~ o,~. G~ o~ w~ . ~ ....... ..... ~-~'" ,'" I,, , ii' i ' If b.-_. ,., . - ~-~ ~ .... . '~. ;.. ,..,.. .. .] '~ .-. CZ ' '. -,--~ - ,., ~-- ... .t.., .... 2:' ,: l -- t DAT~ 11-21-68 wELL NO D-Il 'LEASE STATE Alaska MARATHON OIL COr~PANY HISTORY OF .OIL OR GAS WELL.. Trading Bayi....Unit PAriSH COUNTY. Kenai Borough SEC. __32" TWP.__9_N FIELD McArthur River KB EL£V. 106 ' ,, rToP of Oil STRING __ ELEV.__ / MEASUREMENTS TAKEN FROM ~TOP OF ROTARY TABLE. ELEV., / ~GRD. OR MAT, ELEV._ HISTORY PREPARED BY Owen W. Akins TITL£ Drilling. Superintendent It is of the greatest importance to have a complete history of the well. Use this form in reporting the history of all important operations at the well, together with the dates thereof, including size of hole, size and number of bits, complete description of casing, cementing, fishing or drilling difficulties, surveys, all tests, all completion operations and procedure, etc. DaTE 8/30/68 8/31 9/1 912 9/3 9/4 TD 400' - Rig released at 12:00 midnight. Skid to Slot 3, Leg A-2. Rigged up on D-Ii. Cleaned out drive pipe to 400'. Rigged up and ran Sperry Sun gyro.. TD 1025' - Gyro Survey at 375', 0 deg 15 mins, total displacement from center leg 6.38' north, 1.44 ft west. Spudded at 11:30 AM8-31-68. Drilled 17%" hole from 400' to 655'. Pulled out, ran Turbo #1, turbo 6-3/4" with 2° kick sub. Faced north. Drilled from 655' to 826'. Pulled out and ran drilling setup. Drilled and surveyed from 826' to 1025'. TD 1940' - Drilled from 1025-1462'. Pulled out of hole. Picked up turbodrill. Ran in hole. Turbo stopped at 1050'. Could not ream to bottom. Pulled out of hole. Ran in hole with drilling setup. Drilled to 1685'. Conditioned mud. Pulled out for Turbo. Ran Turbodrill #2, 6-3/4" with 2%° kick sub. Drilled to 1735'. Pulled out. Ran drilling setup. TD 2550' - Drilled and surveyed 12~" hole from 1940' to 2115'. Pulled out of hole'to change drilling assembly. Drilled and surveyed 12~" hole from 2115' to 2550'. Pulled out of hole, laid down 57 joints 5" drill pipe and 2 monel drill collars. Picked up 17~" hole opener, and opened 12~" hole to 17½" from 655' to 2140'. Opened 17%" hole at 2140'. TD 2550' - Opened 12~" hole to 17~" from 2140' to 2523'. Circulated one hour. ~Pulled out of hole to 600'. Reran to 2523 and circulated' one hour. Spotted 20 sacks nut plug. Pulled out of hole strapping drill pipe - no correction. Rigged up to run 13-3/8" casing. Ran 62 its 13-3/8", 61#, J-55, Range 3 buttress casing 2461.10' net pipe, set at 2510.57'. Ran 4 centralizers on bottom two joints. Spot welded collars on bottom 3 joints and top two joints. Circulated hole for 45 minutes. Rigged up BJ and cemented 13-3/8" casing with 2000 sacks Class "G" cement with 6% gel followed by 400 sacks Class "G" cement with 2% calcium chloride. Cement mixed with Inlet water, 400 sacks tail-in mixed with fresh water. Total mixing time 105 minutes. Displaced plug with rig pump in 35 minutes. Bumped plug with 1500#, checked floats - held OK. Final cementing pressure 1100#. Lost partial returns while displacing cement. Lost approximately 85 bbls of mud. Job complete at 2:45 AM. Picked up blowout preventers and centered casing. Fluid level standing at top of piling. Waited on cement. TD 3060' - Waited on cement 3 hours. Backed out landing joint and nippled down BOP's. Ran 6 its 2-1/16 tubing between 33" piling and 13-3/8" casing. Tagged .top of cement at 224'. Cemented down 2=1/16 tubing with 750 sacks Class G neat cement. Cement circulated with good returns throughout job'. Pulled tubing. Installed 13-3/8", 3000# bradenhead and nippled up BOP's. Tested BOP's to 3000# for 30 minutes, held OK. Tested casing to 1500# for 30 mins, held OK. After waiting on cement 19~ hours, drilled float collar and shoe at 10:15 PM. Drilled and surveyed 12~" hole from 2550' to 3060'. Pulled out of hole to change drilling assembly. Went in hole at 3060'. DEC 4 196q _DIVISION OF O1~. AND ANCHOt~.GE. .DATE PAGE 2 MAg~ATHOIM OIL COP4PAi~IY HISTORY OF OIL OR GAS~,WELL FIELD WELL NO, D-11 STATE BLOCK LEASE Trading Bay Unit.i - SEC. TWP R PARiSh COUNTY I Top df OIL STRING .. i ELEV.-- HISTORY PREPARED BY MEASUREMENTS ToP OF ROTARY TABLE . . ELEV.__ TITLE TAKEN FROM [ORD. OR MAT ELEV.__ It is of the greatest importance to have a complete history of the well. Use this form in reporting the history of all important operations at the well, together with the dates thereof, including size of hole, size and number of bits, complete de~cdption of casing, cementing, fishing or drilling difficulties, surveys, all tests, all completion operations and procedure, etc. ~[~.ii~?_~ DATE 1968 9/5-6 9/7-10 9/11 9/12 9/13 9/14 9/15 9/16 9/17 13-3/8" Casing Detail Description KB to Top of Csg.-._' 61 its 13-3/8" 61~'J-55 Buttress 1 Baker Fill Collar ~'- 1 jt 13-3/8" 61# J~55 Buttress 1 Baker Fill Shoe DEC DI¥1$1ON OF O1~_ AND GAS Effective From TO O' 44--780 2425.98' 44.80' 2470.78' 1.95' 24'70.78' 2472.73' 35.12' 2472.73' 2507.85' 2.72' 2507.85' 2510.57' TD 5057' - Drilled and surveyed 12~" hole. Pulled out to run turbodrill. Picked up 6-3/4" turbo with 2½° kick sub. Set Turbo #3 at 4931'. Faced N 10° E. Drilled 4994'. Pulled out. Ran drilling setup. Drilled from 4994' to 5057'. Pulled out to change drilling setup. TD 7060' - Drilled and surveyed 12~" holeo Made up turbodrill at 7060'. 'TD 7399' - Ran in hole with Turbodrill #4, 6-3/4" OD with 2%° kick sub and 9,7/8" bit. Faced tool N 6 E, full left turn. Drilled from 7060 to 7092' with turbodrill. Pulled out of hole and ran in hole with a follc~zing drilling assembly (limber). Reamed 9-7/8" rat hole to 12~". Drilled and surveyed 12~" hole from 7092' to 7399'~ TD 7674' - Drilled and surveyed 12~"~..hole .from 7399 to 7666'. Pulled out of hole and picked up Turbodrill #5, 9-7/8" bit and 2%° kick sub. Ran in hole with turbodrill and oriented face of tool for full left turn. Drilled 9-7/8" hole with turbodrill from 7666' to 7674'. TD 8055' - Drilled with turbodrill from 7674' to 7698'. Pulled out of hole and ran in hole with a following drilling assembly (limber). Reamed 9-7/8" rat hole to 12~" from 7666' to 7698'. Drilled and surveyed 12~" hole from 7698' to 8055'. TD 8200' - Drilled and surveyed 12~" hole from 8055 to 8200'. Pulled out of hole to run Turbo #6. TD 8322' - Ran in hole with Turbodrill #6, 6-3/4", 2~° kick'sub, 9-7/8" bit. Could not orient tool Pulled turbo. Ran in with drilling setup. Drilled from 8200-8322'. Pulled out to run in with turbo 6-3/4" With 2~° kick sub, 9-7/8" bit. Oriented tool. TD 8367' - Oriented Turbo #7. Set full turn to left. Drilled'from 8322-8332'. Ran survey and Checked orienting. Turned tool 50° to left. Drilled from 8332-8367'. Pulled out and ran Bit #21 - 12~ RR, 2 - 6~ monels, stabilizer, 2 DC, stabilizer, 4 DC, stabilizer, 3 DC, stabilizer, B.S. Opened 9-7/8" hole to 12~" to 8367'. Survey showed N 25° E. Pulled out of hole, ran in hole with locked set up and redrilled from 8332' to 8367'. Survey sh~ed N 22E. TD 8404' - Ran in hole with 6-3/4" turbodrill, 2%° kick Sub and 12~" bit. Oriented turbodrill for full left turn. Drilled with turbodrill 8 from 8367 to 8385 ft. Pulled out of hole and picked up a limber drilling assembly. Drilled 12~" hole from 8385' to 8404'. Survey at 8404' sh~,zed direction N 25 E. Pulled out of hole to pick up rebel tool. PAGE 3 -DATE MARATHI3N OIL CoMpANY HISTORY OF OIL OR GAS~WELL WELL NO._ D-Il LEAS~' STATE Trading Bay Unit PARISH COUNTY. BLOCK SEC., ELEV. I ToP (~f OiL STRING __ ELEV.- . HISTORY PREPARED BYi MEASUREMENTS{.TOP OF ROTARY TABLE.... .ELEV. TITLE TAKEN FROM / / [GRD. OR MATi ELEV,_ FIELD TWP R. .. It is of the.greatest importance to have a complete history of the well. Use this form in reporting the history of all important operations at the well, together with the dates thereof, including size of hole, size and number of bits, complete description of fishing or drilling difficulties, surveys, all tests, all completion operations and procedure, etc. DATE 1968 9/18 9/19 9/20 9/21 9/22 9/23-24 9/25 9/26 9/27 DE C g zl I96S .. DIVISION OF OIL AND OA~ ANCHORAGE TD 8371' - Ran rebel tool. Drilled from 8404' to 8535'. Pulled out to change bit. Ran in with same drilling setup. Drilled 12~" hole from 8535'-8571'. TD ~778' - Laid down ·rebel tool. Ran in with drilling setup. Drilled from 8751'-8778'. -. " TD 8878' - Drilled to 8842'. Pulled out to run Turbo ~in #9, turbodrill 6-3/4" with 2~° kick sub. Set full turn to left. 'Drilled from 8843'-8878' (35') in 3 hrs. Pulled out of hole. Ran in with drilling setup, and opened 9-7/8" hole. TD 9032' - Finished opening 9-7/8" hole to 12~". Drilled and surveyed 8878' to 9032'. Started out of hole. Pulled 2 stands and started pulling hard. Rotated and worked pipe 2~ hours. Worked free. Pulling out of hole for bit and to change drilling setup. TD 9280' - Completed trip for bit. Drilled 12~" hole from 9032' to.9280'. Pulled out at 9280' for bit chan~e. Surveyed at 9280', no good. Pulled tight on connection at 9243'. Pulled free on trip. Went in hole. TD 9700' - Drilled and surveyed 12~" hole. Pump pressure began to drop off. Pulled out of hole. Jet in bit was washed.out. Changed bit. Ran in hole. Drilled from 9675' to 9700' and circulated and conditioned hole for logs. TO 9700' - Pulled out of hole and rigged up Schlumberger. Ran DIL from 9700' to 2510', BHC Sonic 9700-2500', Density from 9700'-2514', High Resolution Dipmeter from 9694'-2514'. Rigged up and ran Sperry Sun Gyro. TD 9700' - Continued running Sperry Sun Survey.' Ran in hole with drilling setup. Circulated and conditioned mud to .run 9-5/8" casing. Dropped survey, pulled out of hole. Tight hole at 6400'. Installed 9-5/8" rams and ran 208 jts (8607') of 9-5/8" casing. Started csg at 10:00 PM. Ran 9-5/8" casing. 9-5/8" Casing Detail KB to Top of Csg. 125 its 9-5/8" 40# N-80 Buttress 37 its 9-5/8" 43.5#, N-80 Buttress 36 its 9-5/8" 47#, N-80 Buttress 33 its 9-5/8" 47#, RS-95 LT&C 1 Baker Fill Collar 2 its 9-5/8" 47# RS-95 LT&C 1 Baker Fill Shoe 0' 42.88' 5195.44' 42.88' 5238.32' 1522.10' 5238.32 6760.42' 1454.83' 6760.42' 8215.25' 1386.85 ' 8215.25 ' 9602-. 10 ' 2.00' 9602.10' 9604.10' 84.60 ' 9604.10 ' 9688.70 ' 2.00' 9688.70' 9690.70' rD 9700' - Completed running 233 its of 9-5/8" casing with shoe at 9690.70'. Float collar at 9604, Baker centralizers on bottom 4 joints, circulated 1 hour. Ran 500 gallons mud sweep ahead of 2400 sacks Class "G" cement blended with 8% gel, 0.5% R5 and 0.8% D-31 mixed in 500 bbls sea water followed with 200 sacks Class "G" mixed in fresh water, cement 13.5# to 14# per gallon slurry. Started mixing at 10:20 ~Jl. Completed at 12:00 Noon, displaced with rig pumps, circu- DaTE I~IAI~ATHON O.IL IDEIMPANY HISTORY OF Oil or GAS WELL FIELD. WELL NO....D-11 STATE LEASE Trading Bay Unit PARISH COUNTY ELEV. __ BLOCK SEC. TWP R..i t ToP Of OIL STRING ElEV.- - .HISTORY PREPARED BY MEASUREMENTS TOP OF ROTARY TABLE i i i ELEV. TITLE TAKEN FROM [GRD. OR MAT ELEV.__ It is of the greatest importance to have a complete history of the well. Use this form in re~,ortin~l the history of all important operations at the well, together with the dates thereof, including size of hole, size and number of bits, complete description of casing, 'cementing, fishing or drilling difficulties, surveys, all tests, all completion operations and procedure, etc. 'DATE 1968 ~/28 _-'/29-10/5 13/6 :3/7-8 :3/9 toni 1.ating pressure 1600 increased to 2500#. Bumped plug with 3000#, full circu- lation throughout job. Circulated out approximately 150 sacks at surface. Job completed at 1:14 PM 9-27-68. Set slips and cut off 9-5/8" casing. . . Installed pack off-and spool. Tested with 2500~, OK. Installed BOP and riser. Tested with-.3000#, OK. Went in hole with drilling setup. .. TD' 9930' - Continued going in hole. Waited on cement 23 hours. Drilled out float at 9604'. Cleaned out cement to 9670'. Tested casing with 2500#, OK. Drilled out cement and shoe at 9690'. Continued drilling 8%" hole. TD 11,205' - Drilled and surveyed 8~" hole. .Tripped to change bit. Tight hole from 10,770' to 10,660' Hole sloughing, changed 4 stabilizers. Ran in hole. Cleaned out from 10,860~ to 10,900'. Drilled 8~" hole from 11,102' to 11,205'. TD 11,348' - Drilled and surveyed 8~" hole. Tripped at 11,278'. Lost bearing out of one cone on Bit #47. Hole condition improved. Tripped at 11,348'. Hole condition good. Went in hole with Bit #49. TD 11,682' - Drilled 8~" hole. Circulated for logs. Pulled out of hole to log at 4:30 AM. TD 11,682' - Rigged up Schlumberger. Ran Dual Induction Log. Bore Hole Compen- sated Sonic, Formation Density, Dipmeter. Rigged down Schlumberger. Ran in hole and conditioned for liner. Rigged up to run liner, Ran 7" liner. TD 11,682' - Ran 7" 29# N-80 X-line liner. Used Baker Loc on shoe, collar and bottom 2 its. Ran 4 B&W centralizers on bottom 2 joints, one each on next 16 its and 2 each on top 6 its. Circulated one hour. Set hanger. Pumped 500 gallons mud. sweep ahead. Mixed 600 sacks Class "G" treated with 0.5% R5 and 1% D-19 with fresh water. Bumped plug a~-3:20 PM with 2000 psi. Bled back 3 barrels. Set packer and reversed out approximately 50 barrels cement. 'Laid down 5" DP. Picked uP 3~" DP with 8½" bit and scraper. Cleaned out 9-5/8" at 9420' after 16 hours. 7" Liner Detat.t. Top of Liner Brown Packer & Hanger 46 its 7" 29# N-80 Xline Brown Landing Collar 2 its 7" 29# N-80 Xline' Brown Cement Shoe Effective From To - - 94~-0-7.00' 19.40' 9440.00' 9459.40' 1966.05' 9459.40' 11,425.45' .95' i1,425.45' 11,426.40' 85'67' 11,426.40' 11,512.07' 1.72' 11,512.07' 11~513.79' PBTD 11,425' - Cleaned out 9-5/8" csg to top of liner at 9440'. Ran 6" bit and 7" scraper. Tagged top of liner at 9440' and PBTD at 11,425'. Circulated two hours. Pressure tested liner lap to 2000 psi for 30 minutes, OK. Rigged up Schlumberger. Ran Cement Bond Log and Gamma Correlation Log. Ran Baker retrievable DST tools. ~-~-~, ~ ,DIVISION O~ Olt AND GA3, DATE PAGE 5 MARATHON OIL COMP,~I~Y HISTORY OF OIL OR GAS~WELL FIELD WELL NO. D-ih i LEASE T~_~d_!n~ Bay Unit PAriSh STATE COUNTY ELEV. MEASUREMENTS TAKEN FROM BLOCK SEC I Top Of OIL STRING ELEV __ TOPOF ROTARY TABLE . .ELEV.__ GRD. OR MAT. ELEV._ TWP R.. HISTORY PREPARED BY TITLE It is of the greatest importance to have a complete history of the well. Use this form in reporting the history 'of all important operations at the well, together with the dates thereof, including size of hole, size and number of bits, complete description ~~g,~.enting, t'-'"~ F'~ ~ ~'-!~ -i.~t ~--' ~i~ fishing or drilling difficulties, surveys, all tests, all completion operations and procedure, etc. ~'~ ~ ~ DATE 1968 lO/12 10/13 D E C 2 &. 196 DIVISION OF OIL AND GA~ .. ANCHO~J~.GE PBTD' 11,425~ - Drill Stem Test #1 liner lap witk Baker Model "C" full bore set- down retrievable cementer. With 1000' fresh Water cushion~ set packer at 9420' with 5' tail.~' Open 60 minutes, weak blow for 5 rains and died. Pulled tool loose at 9:00 AM. Recovered 20' mud with water cushion· Charts indicated tool open-With no plugging. Laid down tools, ran. in with bit and · changed over to diesel - 30728 gallons diesel. Pulled out, laid down drill pipe. Rigged up Schlumberger and ran ring gauge. Rigged up to run 26-32# AGT packer. PBTD 11,425' ~ Set 26-32# AGT packer with Schlumberger at 10,818'. Rigged up and ran 48 joints 3%" seal lock N-80 and 281 joints 4%" seal lock tubing. Total of 329 joints with one pup joint. See tubing tally for valve spacing. Ran gas valves with sleeve open - spaced out and tested tubing with 2000 psi. Tested ~" tubing with 5000 psi. Removed BOE and installed Xmas tree. Tested tree with 5000 psi and tested ~" tubing 5000 psi. AGT packer at 10,811' tubing measurement. Tail at 10,833'. Rigged up and pulled dummy valve. Landed tubing on AGT packer with 15,000# on packer. 3~ and 4½" Tubing Detail Elevation CIW Hanger 4%" N-80, SL Pup Jr. 4~" N-80 SL Tbg 7 its z - Otis Ball Valve 82 its 4%" N-80 Seal Lock tubing VI C2F #177 56 its 4%" N-80 Seal Lock Tbg. V2' C2F #175 45 its 4%" N-80 Seal Lock tbg V3 C2F #165 32 its 4%" N-80 Seal Lock Tbg V4 C2F #167 30 its 4%" N-80 Seal lock tbg V5 C2F #174 9 .its 4%" N-80 Seal-Lock'Tbg V6 C2F #178 9 its 4%" N-80 Seal Lock Tbg V7 C2F #173 9 its 4%" N-80 Seal Lock Tbg V8 C2F #168 2 jts 4%" N-80 Seal Lock Tbg 4%" x 3~" Seal Lock X-over 7 its 3%" N-80 Seal Lock Tbg V9 C2F SN #202 10 its N-80 Seal Lock Tbg V10 C2F SN #170 7 its 3%" N-80 Seal Lock Tbg VII C2F SN #156 6 its 3%" N-80 Seal Lock Tbg Effective From -40.80' .1.00 ' 40.80 ' 7.32' 41.80' 232.80 ' 49 · 12 ~ 2.95~ 281.92' 2710.14' 284.87' 4.45~ 2995.01' 1837.42~ 2999.46' 4.45' 4836'.88' '1468.58' 4841.33' 4.45~ 6309.91' 1043.19~ 6314.36' 4.45~ 7357.55' 976.16' 7362.00' 4.45' 8338.16' 300.52' 8342.61' 4.45' 8643.13' 295.99' 8647.58' '4.45' 8943.57' 297.16' 8948.02' 4.45' 9245.18' 66.45' 9249.63' .72' 9316.08' 213.94' 9316.80' 4.45' 9530.74' 309.65 ' 9535.19 ' 4.45' 9844.84' 213.33' 9849.29' 4.45' 10,062.62' 180.46' 10,067.07 ' To 41.80 ' 49.12' 281.92 ' 284.87 ' 2995. O1 ' 2999.46' 4836.88 ' 4841.33 ' 6309.91' 6314.36' 7357.55' 7362.00' 8338.16' 8342 61' 8643.13 ' 8647.58 ' 8943.57 ' 8949.02 ~ 9245.18' 9249.63 ~ 9316.08~ 9316.80' 9530.74' 9535.19 ' 9844.84' 9 849.29 10,062.62' 10,067.07' 10,247.53 ' DATE PAGE 6 ~V~Ai~IATHD~J, OIL C(3iVIPANY HISTORY OF OIL or GAS WELL FIELD BLOCK WELL NO. ])-11 LEASE Trading Bay Unit SEC. PARISH STATE COUNTY __ ELEV.. __ ' rTOP OF OIL STRING , ELEV .... HISTORY PREPARED BY MEASUREMENTS TOP OF ROTARY TABLE ELEV. __ TITLE TAKEN FROM ~GRD. OR MAT. ELEV._ TWP R,, It is of the greatest importance to have a complete history of the well. Use this. form in reporting the history of all important operations at the well, together with the dates thereof, including size of hole, size and number of bits, complete description of casing, cementing, fishing or drilling difficulties, surveys, all tests, all completion operations and procedure, etc. DATE' 1968 10/14 V12 C2F SN #161 7 j ts 3~z" N-80 Seal Lock Tbg V13 C2F SN #176 '6 its 3½" N-80 Seal Lock Tbg V14 C2F SN #167 4 its 3~" N-80 Seal Lock Tbg 3~" Type "C" Sliding Sleeve 1 jt 3~z'' N-80 Seal Lock Tbg 3~" Seal lock x 2-7/8" EUE 8rd 2-7/8" EUE 8rd "P" Landing Coupling 3.500 OD A1 Seal and 3 seal units Seal Unit Guide Nut 7" 26-32 AGT Packer 4~" 8rd Extension 4~" 8rd Coupling 4~" 8rd x 2-7/8" EUE 8rd X-Over 2-7/8" EUE 8rd Pup jt with Collar 2-7/8" Otis X Nipple 2.31 ID 2-7/8" EUE 8rd Pup jt with Collar 2-7/8" Otis X nipple 2.31 ID 2-7/8" EUE 8rd N-80 Pup Jr. · 2-7/8" EUE 8rd Wing Guide 4.45' 10,247.53' 10,251.98' 215.67' 10,251.98' 10,467.65' 4.45' 10,467.65' 10,472.10' 182.51t 10,472.10' 10,654.61' 4.45' 10,654.61' 10,659.06' '123.10' 10,659.06' 10,782.16' 2.75' 10,782.16' 10,784.91' 30.91' 10,784.91w 10,815.82' .68t 10,815~82' 10,816.50' .40' 10,816.50' 10,816.90' 4,56' In Packer .65' In Packer 2.68' 10,816.90' 10,819.58' 5.54' 10,819.58~ 10,825.~2~ .50' 10,825.12' 10,825.62' .40~ 10,825.62' 10,826.02' 5.80~ 10,826.02' 10,831.82' .87t 10,831.82' 10,832.69' 5.54~ 10,832.69t 10,838.23' .87 ~ 10,838.23 ' 10,839.10 ' 9.93' 10,839.10' 10,849.03' .96~ 10,849.03~ 10,849.99' All USI Mandrels ran in hole with sleeves open. 15,000 wt set on packer. Hook load of string.upward 150,000 X line. PBTD 11,425' - Perforated with Schlumberger, Code /SCR-72/ through tubing gun. Four holes per ft. Started perforating at 0900. Job completed at 1700 10-14-68. Shut in pressure on tubing 40#, opened well into well clean tank~. WOuld not fl~. Perforated from 10,902' to 10,976 - 74 ft, 11,000' to 11-154' - 154', 11,194' to 11,300 - 106~, 11,330' to 11,390 - 60', Total of 394'. Released rig at 1800 10-14-68. . O~O~ ~ TRADING BAY UNIT D- 11 BIT RECORD PAGE 7 Bit # 1 1 2 3 4 3RR HO1 5 RR5 6 7 RR4~ 9 10 11 12 13 14 15 16 17 18 19 2O 21 RR20 RR21 22 RR22 RR?2 23 24 25 26 RR25 27 28 29 3O 31 32 RR32 33 34 35 36 37 39 &O 41 42 43 44 45 46 47 48 49 5O 51 5 IRR 52 Size 17½ 12~ 9-7/8 9-?/$ 9-7/8 12~ 9-7/S 12~ 9-7/8 12~ I! · Make Reed Hughes Reed HTC Sec HTC Hughes Globe Hughes Reed Sec Reed Sec HTC Reed Reed HTC Sec Hughes Reed HTC Reed Hughes Reed HTC Sec Sec Reed Hughes Sec HTC Reed Sec Reed HTC Reed Hughes Reed Hughes Sec HTC ST1AG T3A ST1AG X3A ST1AG X3A 'OSC X3A ST1AG ST1AG OS C3 OSC3 OSC3 XDG ST3G XDG ST1AG S4TG ST1AG S4TG ODG ST1AG XDV S4TG ODV ST1AG ODV ST1AG ODG ST1AG XDG S4TG S4TG ST1AG XDG S4TG ODV YS1GJ M4NG YHG XDR ST1AG XDR SCM XDR M4L M4L W7R Depth on Depth off Ftg Hfs Condition Clean 400 655 1462 1685 1737 650 2550 306O 4193 4931 4994 5311 5887 6366 6477 6803 6946 7060 7092 7399 7666 7698 8055 8200 82OO 8322 8322 8322 8367 84O4 8535 8641 8751 8843 8878 8960 9032 9306 949O 9599 9675 9700 9700 9808 9969 10,063 10,157 10,300 I0,369 10,437 10,533 10,621 10,740 10,890 10,978 11,078 11,180 11,278 11,348 11,395 11,527 Clean Clean out - drive pipe 655 55 4k good 1462 807 12~ T4-B2 1685 223 1-3/4 T6-B1 1737 52 2 TI-B1 2550 813 4~ T4-B2 2523 1868 14k T6 3060 510 5~ Ti 4193 1133 10-3/4 T6 4931 738 10~ T5-B3 4994 63 3 T4-B3 5311 317 10 T5-B3 5887 576 12~ T5-B3 6366 479 13~ - 6477 111 3 T6-B1 6803 326 9~ T7-B3 6946 143 4% T5-B2 7060 112 2-3/4 T4-B3 7092 32 2 T2-B1 7399 307 8-3/4 T5-B2 7666 267 8~ T7-B4 7698 32 2-3/4 T2 8055 357 10 T4 8200 145 5~ T4 Did not get turbo oriented 8322 122 6 T3 8367 45 4~ T2-B4 8367 Open 9-7/8 ot 12~ 8367 Redrill to sidetrack hole 8404 37 4~ - 8535 131 1~ T4-B2 8641 106 7~ T3-B! 8751 110 6 T5-B3 8843 92 6~ T2-B2 8878 35 3 T2 8960 72 4~ T4-B4 9032 72 5 .T2-B2 9280 248 13~ T4-B4 9490 184 10~ T6-B2 9599 109 11~ T6'B4 9675 76 3~ Washed out 9700 25 2~ - Cond. Hole 9808 108 7~ T7 9969 161 7 T5-B3 10,063 94 3 T6-B3 10,157 94 44 Pull out 10,300 143 7 T4 10,369 69 4~ T5 10,437 68 34 TT-.B2 10,533 96 5~ T5-B4 10,621 88 10 T4-B5 10,740 119 6~ - 10,890 150 8 T2-B1 10,978 88 7 TS-B4 11,078 100 9 T8-B3 11,180 102 13 T8 11,278 98 9 T8 11,348 70 5~ - 11,395 47 5 T6-B1 11,52.7 132 11 T4-B6 11,682 155 9 - out - run to 9440' out run to 11,425' SYMBOL OF SERVICE REPORT of SUB-SURFACE DIRECTIONAL S.URVEY MARATHON COMPANY TRADING i, BAY UNIT WELL NAME COOK INLET, ALASKA LOCATION JOB NUMBER AM8-1868 TYPE OF SURVEY SINGLE SHOT DA~ AUG.- SEPT. UIHO IY EA~I~.O IN U. $. A. SURVEY BY ANCHORAGE OFFICE :R WELL COMPLETION REPORT PAGE 1 MEASURED .... DEPTH -- 100, 200. · 300. 400, 500, 6.00, - - 700, 800, .- ....900· 1000. -- 1100. 1200. 1BO0· 1400, .... 1 500. 1600. --- 1700. 1800. · 1900. 2000, ...... 2100· -. 2200, .... 2300, 2400, -2500. 2550. ..... 2701., - 2889 · .- 3047. 3200. 3472, COURS LENG 100 100 100 100 100 100 100 100 100 100 100 100 100 100 100 100 lO0 100 100 100 100 100 100 100 100 50 .,151 188 158 153 272 MARATHON OIL COMPANY O-ll PREPARED FOR EASTMAN BY SCS E -- D E V I A T I O N - C 0 U R S E T 0 T A L TH ANGLE - DIRECTION- AMOUNT--- V,DEPTH .... LATITUDE--- DEPARTURE ........... V,DEPTH LATITUDE .... DEPARTURE- · 0 O' N · 0 O' N . --0 "0' N- · 0 45 · 0 45 · 0 30 · 2 15 · 7 15 · 9 45 , I1 15 · i2 45 · 14 i5 · i6 30 . 18 45 · 20 45 OW ............ O, 0 W O, 0 .... W ................ O, ' N 83 W l. " ...... N "86 W ............... 1 . ' N 53 W O. '- N- 9 E ....... 3. ' N 11 W 12. ' N 16.-W ............... 16. ' N 15 W 19. ' ...... N 14~, W ................... 22. ' N 14 W 24. ' N 15-W ......... 28. ' N 15 W 32. ' ....... N- ,1.7---- W ............. 3 5 · O0 100.00 ...... 0.00 N ...... 0.00 W - -- 100.00 6.60.- N -~- 0.40 W O0 100.00 0.00 N 0·00 W 200.00 6.60 N 0o4C O0 t00.00 ............ O.O0-N ............ O.O0--W ............. 300.00 ....... 6.60 N .............. 0.40"'~' - 30 99.99 0.15 N 1.29 W 399,99 6,75 N 1.69 W 30 ...... 99.99 ........... O.09~N .............. 1.30 W ........ 499-.98 ........... 6.85 N ........... 3.00-W- 87 99.99 0,52 N 0.69 W 599,97 7,37 N 3.70 W 92 .....99.92 ........ 3.87 N .............. 0.61..E ....... 699.90 11.25 N ..... 3.08 W 61 99,20 12.38 N 2,40 W 799.10 23.64 N 5.49 W 93 ....... 98.55 ........... 16.27 N ..........4.66~-W ............. 897.65 ....... 39.92-N ........ lO.16--W 50 98.07 18,84 N 5,04 W 995,73 58.76 N 15,21 W 06---97.53 .......... 21.4t-N ............. 5.33---W .......... 1093.27 ....... 80.17-N .......... 20.55 .... 61 96,92 23,88 N 5,95 W 1190,19 104,06 N 26.50 W 40 --95.88 ...... 27.43 N ............. 7.35-W ......... 1286.07 ..... 131.49 .N .......... 33.85-W .... 14 94.69 31.04 N 8.31 W 1380,76 162,54 N 42.17 W 42 ........ 93.51 ........... 33.88~N ...............10.35-W ............ 1474.28 ....... 196.42-.,N .......... 52.53--.W · 23 15 · 24 45 · 25 15 · 28 15 · 31 0 . 33 30 · 34 30 · 35 15 · 36 0 · 36 15 . 36 15 · .,.37 45 · 39 0 . 40 0 . 39 30 37 45 ' N 19 W 39,47 91.87 37,32 N 12.85 W 1566.16 233,75 N 65.38 W ' N 14 -W ...............41.86 .... 90.81 ........ 40..62-..N ....... lO.12-W ........... 1656.97- 274.37..PN ............. 75.51 .W .... ' N 9 W 42.65 90.44 42.13 N 6.67 W 1747.42 316.50 N 82.18 ' N .-8-~W ..............47.33 ...... 88.08 ......... 46.87 N .......... 6.58 W ....... 1835.51 ....... 363.37.N. ~. 88.77~..f.. ' N 17 W 51,50 85,71 49,25 N 15,05 W 1921,22 412,62 N 103,83 W ' .... N ...... 8..W .......... 55.19 .... 83.38 ........... 54.65-.N .............. 7.68 .... W ........... 2004.61 ......... 467.28-N ' N 8 W '- .N. 8-W ' N 8 W ' N -9 W 56. .......... 57. 58. ....... 59. ' N 8 W 29. '.--N 7-W ................. 92, ' N 7 W 118, '-~N .-9. W ...... 101, ' N 10 W 97. ' N 7 W ........... 166. · 64 82.41 56.08 N 7.88 W 2087.02' 523.37 N 119.39 W 71 81.66 ........ 57.15 N ........... 8.03..W ....... 2168.69 77 80-90 58,20 N 8,18 W 2249,59 638,73 N/,135 61W .... ...... ............ ......... .. N w N w 4¢,-119.39 .......... 91.75-N .............. 11.26~W .......... 2489..95 ..... 818.17-N ............ 160.24-W w N < o7.4 w MEASURED COURS ......... DEPIH LENG W E L L C 0 M P L E T ! 0 N R E P 0 R T PAGE 2 MARATHON OIL COMPANY D-ii PREPARED FOR EASTMAN BY SCS E - - D E V I A T I 0 N - C 0 U R S E T 0 T A L TH ANGLE ...... DIREGTt-ON ....... AMOUNT~..V.DEPTH ..... LATITUDE ........ DEPARTURE ........ V.DEPTH ......... LATITUDE.---DEPARTURI ........ 3772 4005 ...... 4192 4494 -..4806 4930 5006 5056 · 5239 5291 ....... 5.552 5842 · 6053 6366 6463 6588 ...... 6686 6803 .... 6946 7055 7118 7211 ....... 7305 7399 ..... 7560 7666 ..... 7768 783O ..... 8055 8194 ...... 8320 300 '233 187 302 312 124 76 50 183 52 261 290 2~1 313 97 125 98 117 143 109 63 93 94 94 161 106 102 62 225 139 126 33 15' .......... N--IO-W ......... 164.48-250..88 ...... 161. 31 BO' N 9 W 121.74 198.66 120· 30 45' ...... N .9-W ........ 95.61-160,70 ...... 94. 30 30' N 8 W 153,27 260.21 151. 30 ~45~ ......... N ....6--W .......... 159.52-268,13 ....... 158. 98-N ...........28.56 .... W .......... 3341.10 ..... 1459-.02 .... N ........ 256.'30 W 24 N 19.04 W 3539.77 .1579.26 N 275.34 W 43-.N ........... 14..95-W .............3700.47 ...... 1673'-.70--N .- 290.30 W- 78 N 21.33 N 3960.69 1825.48 N 311.6~ W 64 N ...........1.6.67-W .............4228.82 ....... 1984-.-.1.3 ....N ........ 328..3~..MW 30 30' N 6 W 62.93 106.84 62.58 N 6.57 W 4335.66 2046.72 N ~ 334.89 30 15' -N ...... 2-.E~ ............. 38.28 ..... 65.65 ............ 38,26.,N .............. 1.33,--E .............. 4401.,31 .... 2084.98 N ..... 333,5.5-~W 30 30' N 4 E 25.37 43.08 25.31N 1.77 E 4444.40 2110·30 N 331.'78 e · . o o o o e . 32.-.0' ..... N ..-4.-E ................. 96.97-,155.19 .96. . 31 O' N 5 E 26.78 44.57 26. , - 31--O',~.N ...... 5-E ....... 134.42 223,.72 ......... 133, . 29 15' N 6 E 141.70 253.02 140. . 29 O' .....N.- 6--E ............. 102.29 .... 184,54 ........ 101. . 25 O' N 10 E 132.27 283.67 130. · 24 O' N .....9.-E ................ 39,.45 88,61 .......... 38. . 25 O' N 11E 52.82 113.28 51. . .26 15' ......N .... 11 E ............ 43.34 ..... 87.89 ........ 42, · 27 O' N 14 E 53.11 104.24 51. · - 26. 30' ......N.--16 ..... E 63.8.0-,-.127.97 .......... 61. . 26 30' N 18 E 48.63 97.54 46. . 26 O' ....N 11 .... E ............ 27,61 ._56.62 .... 27. · 27 15' N 12 E 42.58 82.67 41. . 28-.45' ........N-14-.E ............ 45,21 ...... 82.,41 ...........43., · 30 O' N 15 E 46.99 81.40 45. · .. 32 45' ......N ,17 ~E ..............87,09 1.35,40 .......... 83. . 33 30' N 18 E 58,50 88.39 55. .. 30 ...0' ..... N. 14....E ........... 50,99.._ 88,33 ........... 49. · 31 O' · N 14 E 31.93 53·14 30. . ..32 30' ...N.- 16..E ........ 120.89 189.76 ......... 116. . 32 O' N 19 E '73.65 117.87 69. · 31 15' .... N-20 E ............. 65-.36 .....107,71 ........... 61, 73 N .............. 6.76_E ........... 4599.59._.2207.0~ N ..... 325,02..N 68 N 2.33 E 4644.16 2233·72 N 322.68 W 91-N ............ ll.71.-E] ........ 4867.88 ..... 2367.63-N ....... 310..97~;W 92 N 14.81 E 5120.91 2508.56 N~ 296.15 W 73~,N ............. 10,69 E ....... 5305.45 .... 2610.29 N ..... 285,46, W 26 N 22.97 E 5589.13 2740.56 N 262,49 96_N ............... 6.17 E .......... 5677.74 ...... 2779.53_N .......... 256.32.W 85 N 10.07 E 5791.03 2831.38 N 246.24 W 54. N ............... 8.27-..E .............. 5878.92 ..... 2873.93..N ......... 237,97 .W 53 N 12.85 E 5983.17 2925.47 N 225.12 W 33 N ............ 17.58___E ........ 61.11.14 .... 2986.81~N ...... 207,53 .... W 25 N 15.02 E 6208.69 3033,06 N 192,50 W 10 N ............ 5.26.E ............... 6265.32 ..... 3060.17 N ,~ 187·7 W 65 N 8.85 E 6348.00 3101.82 N 86.N ........ 10,93 .E ........ 6430,41 ........ 3145.69.~N ........ 167..44-W 39 N 12.16 E 6511.8~ 3191.09 N 155,28 W 29 N .......... 25.46._E ......... 6647,22 ..... -3274,38 N ...... 129,81W 64 N 18·07 E 6'735.61 3330.02 N 111.73 W 48._N ............... 12.33.~_E ............... 6823.95 ..3379,51N ........ 99,39_~W 98 N 7.72 E 6877.09 3410.49 N 91.67 W 20 N ......... 33.32~E ............. 7066.86 ...... 3526..70..~N ............... 58,35_.W 64 N 23.98 E 7184·73 3596·35 N 34·37 W 42~-..N .......... 22.35 .... E .......... 7292~45...36~.7.77~N .. MEASURED DEPTH 8365. 8493 · 8635. 8744 · 8838. 8913. 8945 · 9032 · 9316. 9442. 9599. 9700 · 9808. 9969 · _10063. 10157. 10300. 10369. -10533. 10621 · 10740. 10890 · ...... 10978. 11078. 11278. 11348. -11527. 11682. ..CLOSURE __ W EL L COMP L ET MARATRON OIL COMPANY D-11 PREPARED __ COURSE - - D E V I A T I 0 N .... C ION REPORT FOR EASTMAN BY SCS PAGE 3 T A L - 0 U R S E LENGTH ANGLE DIRECTION ...... AMOUNT V.DEPTH LATITUDE ...... DEPARTURE ............ V.DEPTH LATITUDE ......... DEPARTURE ... 45,' 31- 0'-- N 22- E .............. 23.17 38,57 · 21,48 N ......... 8-68 IE ............. 7331,03 3679-26'~N ...... 3,33-W ....... 128. 29 45' N 24 E 6'3.51 111.12 58.02 N 25.83 E 7442.15 3737.29 N 22.50 E 142, 28 30' -N 20.E ..... 67,75 124,79' 63,67 N ....... 23.17 E ..... 7566,95 3800,96 N .... 45,67 E 109. 29 15' N 21E ' 53.25 95.10 49.72 N 19.0'8 E ' 7662.05 3850.68 N 64.76 E 94, BO 15' ...... N 23...E ................ 47,35 81,20 ............43,59 N ................ 18,50 .E .............. 7.743,25 3894,-27-N .......... 83.2f' E ......... 75. 29 45' N 18 E 37.21 65.11 35.39 N '11.50 E 7808.36 3929.66 N 94.7~..Z 32, 29 45' ..... N 13. E ............ 15,87 ..... 2'7,78 ....... 15,47 N ........... 3,57 E .......... 7836,15- 3945,14 N ..... 98.33-E 87. 31 O' N 13 E 44.80 74.57 43.65 N 10.07 E 7910.72 3988.80 N ~ 108.41E 284.- 35 O' ,N 15. E ...... 162.89..232.63 .......... 157.34 N ........ 42.16.E ....... 8143'.36. 4146.14 N ~- 150.57-E- - 126. 35 O' N 16 E 72.27 103.21 69.47 N 19.92 E 8246.57 4215.61N ~ 170.49 E 157, 34 30' - N 16 E ............ 88,92 .,129,38 ............. 85,48 .N ............ 24.-51 .... E ......... 8375,96 ..4301,09-N.-~.--t95-00 .... E ...... 101. 34 15' N 17 E 56.84 83.48 54.35 N 16.61E 8459.45 4355.45 N 211.62 E ''~ 108, 34 30,..N---17-E .................. 61,1-7 89,00 ......... 58,49 N ......... 17,88 E ........... 8548,45 4413,95-N ..... 229,51---E ....... 16'1. 34 O' N 17 E 90.03 133.47 86.09 N 26.32 E 8681.93 4500.05 N /255.83 E 94, 34 15' N 18 E ................. 52,90 ...... 77,69 ........... 50,31N ......... 16.34-.-E .............. 8759,63 ~_4550,36..N .-~.272-18 E .... 94. 35 O' N 18 E 53.91 77.00 51.27 N 16.66 E 8836.63 4601.64 N 288.84 E ..... 143, 35- -0' ...... N 18-E .............. 82,02--117.,-13 ......... 78,00.N ............ 25,34- E ............ 8-953,76 ..... 4679,65-.-N .......... 314,19-.E 69. 35 O' N 17 E 39.57 56.52 37.84 N 11.57 E ' 9010.29 4717.49 N ,325.76 E 164,- 37-. 0'-- N 16 E............ 98,69 ..... 130,97 ........... 94,87 N.......... 27,20--E........ 9141,26 4812,37-N _/352..96 .E 88. 38 O' N 16 E 54.17 69.34 52.07 N 14.93 E 9210.61 4864.45 N ¢367.90 E 4934.12-N .... 390.54 E 119. 38 .0' N 18 E ....... 73.26- 93.77 ...... 69.67 N ...... 22.63- E ..... 9304.38 150. 40 O' N 18 E 96.41 114.90 91.69 N 29.79 E 9419.29 5025.82 N 420.2 iE . - 88, 41 _O,.-N.. 17 .... E ............ 57.,-73 ......... 66,41 ............55,21-~N 16,87]~E .............9485.,70--- 5081.,03~N ..... 437,2~E 100. 41 O' N 19 E 65.60 75.47 62.03 N 21.35 E 9561.17 5143.07 N 458.57 E 200, 39 O' -N 20 E ............. 125.86..155.42 - 118,27- N ......... 43..04 E .......... 9716,60 ~ 5261,34 N .... 501.6.2 ~E 70. 39 O' N 20 E 44.05 54.40 41.39 N 15.06 E 97'71.00 5302.74 N 516.68 E 179, 40 0'-.-N 21 .... E ......... 115,05.-137,12 ........ 107.,41--N ...... ~ ...... 41..23-E ........ 9908-,12- 5410,'15 .N .... 557,92 155. 42 O' N 22 E 103.71 115.18 96.16 N 38.85 E 10023.31 5506.32 N ~' 596.77 E 5538.56 ..... N -,~6 .... 11~ E .......................................... 'I No. P--4 STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE MONTHLY RE!PORT OF ~D-RILLING AND WORKOVER OPERATIONS 2, NAME OF OPERATOR Union Oil Company of California* 3. ADDRESS OF OPF_,I~TOR 2805 Denali Street, Anchorage, Alaska 99503 4. IX)CATION O,F Surface- 761.3' N, 1131.5' E from SW Corner, Sec. 6, TSN,. R13W, SM Top of Hemlock- 660' N, 660' E from SW Corner, Sec. 32, TgN, R13W, SM AP1 NUMERICAL ~ODE 50-]33-20]40 LEASE DESIGNATION AND SERIAL NO. ADL-17594 7. IF INDIA)~, ~I_XDTTEE OR TRIBE NAME 8. UNIT,F.AJ:~{ OR LEASE N.~UIE Trading Bay Unit 9. W~:LL NO. D-]l (14-32) 10. FIELD A-ND POOL, OR WILDCA. T McArthur River Field 11, SEC., T., R., M., (BO'I'rOM HOI~ OB.mC~nrE) Sec. 32, TgN, R13W, SM 12. PERMIT NO. 68-73 13. REPORT TOTAL DEPTH AT END OF MONTH, CHA2'~GES IN HOLE SIZE, CASING A_N~D CElVlENTING JOBS INCLUDING DEPTH SET AND VOLI/MES USED, PERFORATIONS, TESTS A/XTD RESULTS, FISI-LING JOB~, JU/~K IN HOLE A/~D SIDE-TRJ%CKED HOLE AN~ ANY OTH~R SIGNIFICANT CI-LA.NGES IN HOI~ CONDITIONS. Tradinq Bay Uni.t D-..ll., Octpber... 1.96.8_ 10/1 - 10/8 Drilled and surveyed 8-1/2" hole from 10,369' to 11,682'. hole to log. Conditioned 10/9 Rigged up Schlumberger; ran DIL, Borehole Compensated Sonic, Formation Density, Dipmeter. Conditioned hole for liner. 10/10 - lO/ll Ran 7" 29 Lb N-80 X-Line Liner; used Baker Loc on shoe, collar and bottom 2 joints,I ran 4 centralizers on bottom 2 joints, one each on next 16 joints and 2 each on top 6 joints Circulated one hour, set hanger,, pumped 500 gallons mud sweep ahead; mixed 600 sacks Class G treated with 0.5% R-5 and 1% D-19 with fresh water. Bumped plug with 2000 psi; set packer and reversed out approximately 50 bbl cement. Cleaned out 9-5/8" casing to top of liner at 9440', ran 6" bit and 7" scraper; tagged top of liner at 9440 and PBTD at 11,425; circulated 2 hours, pressure tested liner lap to 2000 psi, held OK. Rigged up Schlumberger and ran Cement Bond Log and Gamma Correlation Log. 10/12 11)/13 Drill stem test No. 1 liner lap with Baker model C full bore set down retrievable cementer. With 1000' fresh water cushion, set packer at 9420 with 5' tail; open 60 minutes, weak blow for 50 minutes and died. ~!.i~ ~~red 20 ft mud with water cushion, charts indicated tool open ~t~fi ho plugging. Rigged up Schlumberger and ran ring gauge. Se% '2'6-32 lb AGT packer at 10,818'. Ran 48 joints 3-1/2" seal lock 'Nr4~0~1~19°281 joints 4-1/2" seal lock tubing, tested tubing with 2000 psi, ~'i-~d 1/4" tubing with 5000 psi, removed BOE and installed Xmas tree, tested tree with 5000 psi; tested 1/4" tubing 5000 psi. AGT packer at lO,811 tubing mens; tail at 10,833'; pulled dummy valve; landed tubing on AGT packer with 15,000 psi on packer, Form No. 1:'--4 REV. 9-30-67 STATE OF ALASKA OIL AND GAS CONSERVATION COMMIlffEE SUBMIT IN DUPLICA,~I MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS 1. O,L o,. WELL WELL OTHER 2. N~.ME OF OP~ATOR Union 0il Company of California* iiAD]Dt~ESSm__ __ OF O1C)~TOI~ 2805 Denali Street, Anchorage, Alaska 99503 '4. 'LOCA~I~ON OF W~r.?. Surface- 761.3' N, 1131.5' E from SW Corner, Sec. 6, TSN, R13W, SM Top of Hemlock: 660' N, 660" E from SW Corner, Sec. 32 TgN, R13W, SM Apl NUAIERICAL ~ODE 50-133'20140 6. LEASE DESIGNATION AND SERIAL NO. ADL-17594 IF INDIAN, ALO1 tEE OR TRIBE NAME 8. TJI~IT FARA'I OR LEASE NAME Trading Bay Unit g. WELL NO. D-Il (14-32) i0. FLEL,D A_ND POOL. OR WILDCAT McArthur River Field 11. SEC., T., R., A{.. (BO'I'I'OR{ HOLE Sec. 32, T9N, R13W, SM 1~., lm)~dVlIT NO i 68-73 13. REPORT TOTAL D~PH AT END OF MO!NTli, CHA. NGES IN HOLE SIZE, CASING ~ CEMENTING JOBS INCLUDING DEPTH SET ~ VOLUlVIES USED, PERFORATIONS, TESTS AND RESULTS, FISHING JOBS, JUNK IN HOLE A_ND SIDE-T1R~CKED HOLE AD ANY OTHER SIGNIFICANT CI-IANGES IN HOL~ CONDITIONS. Trading B.ay. Unit O,ll, ..October 1..968,_ ..page_ 2 ]0/]4 Perforated with Schlumberger, 4 holes per foot, from 10,902' to 10,976' ll 000' to 11,154' ll 194 to ll 300 ll 330' to 11,390' total of 394'. Released rig at 1800 on 10-14-68. * Marathon 0il Company, Suboperator, Dolly Varden Platform. SZGN~D I[/.~/_ ]~, ~nTL~ Dist. Drlg. Supt. OAT~ 11/14/68 NOTE--Report on this/otto is required for each calendar month, regardless of the status of operations, and must ~ fileU in dupli~te with the Division of Mines }Minerals by the lSth of the succeeding month, unless othe~ise directed. ~ No. P~ STATE OF ALASKA suBMrr m I~UI'LZCA~ REV. 9-~,0-.6'; OIL AND GAS CONSERVATION COMMITTEE MONTHLY RE!PORT OF 'DRILLING AND WORKOVER OPERATIONS 2. NAME OF OPERATOR Union 0i1 Company of California* 3. ADDRESS OF OPERATOR 2805 Denali Street, Anchoraqe, Alaska 99503 4. LOCATION OF W~-~L Surface: 761.3' N, 1131.5' E from SW Corner Sec. 6, T8N, R13W, SM Top of Hemlock: 660' N, 660' E from SW Corner, Sec. 32, ~5. AP1 NUA~ERICAL CODE 50-133-20140 6. LEASE DESIGNATION AND SERIAL NO. ADL 17594 7. IF INDIA)~, ALOTTEE OR TRI~E NAME 8. U'NIT F.~:~lvI OR LEASE NAME lrad~ng Bay Unit g. WELL NO. D-l] (14-32) 10. FI~L~ ~D P~L, OR ~VILDCAT ~cg~thu~ R~ver F~eld 11. SgC., T., g., M., {BOSOM HO~ O~~ Sec. 3~, 19~, RI~, S~ TgN, R13W, SM = ~I~ ~0 m D £ F' ~ I\] ~ ~ 68-73 REPORT TOTAL DEPTH AT END oF MON~-I, CI-L~GES IN HOLE S~,~A~N~ ~' C~TING JOBS INCLUDING DEPTH SET ~ VOL~ USED, P~O~TIONS, ~TS ~ ~SULTS. FISHING JO~, J~K ~ HO~ ~D SIDE-~CKED HOLE Tr.adi.ng Bay 9/1 - 9/2 Unit D-11, September 1968 DIVISION OF MIh:~S & MINERALS ANCHORAGE Dri 11 ed and surveyed 12-1/4" hole from 1025' to 2550', opened 12-1/4" hole to 17-1/2" hole from 655' to 2140'. Opened 12-1/4" hole to 17-1/2" hole from 2140' to 2523', conditioned hole to run casing. Ran 62 joints 13-3/8", 61 lb, J-55, Range 3 buttress casing with shoe at 2510.57', cemented 13-3/8" casing with 2000 sacks Class G with 6% Gel followed by 400 sacks Class G with 2~ calcium chloride gel cement mixed with Inlet water, 400 sacks tail in mixed with fresh water. Bumped plug with 1500 psi, checked floats, held OK. 9/4 Ran six joints 2-1/16 tubing between 33" piling and 13-3/8" casing, cemented with 750 sacks Class G neat cement, circulated with good return throughout, installed 13-3/8" 3000 lb Bradenhead and nippled up BOP's. Tested BOP's to 3000 psi for 30 minutes, held OK. Tested casing to 1500 psi for 30 mins, held OK. Drilled float collar and shoe, drilled and surveyed 12-1/4" hole from 2550' to 3060'. 9/5 - 9/23 Directionally drilled and surveyed 12-1/4" hole from 3060' to 9553'. 9/24 Drilled 12-1/4" hole from 9553' to 9700' conditioned mud to run logs 9/25 9/26 ged up Schlumberger to log, ran. Dual Induction Laterolog, Borehole ompensated Sonic Log, Density Log, High Resolution Dipmeter, and Sperry Sun Gyro Survey. Conditioned hole to run ca~ing and commenced running casing. 9/27 Completed running 233 joints 9-5/8" casing, landed at 9690.70' with float l"orm No. 1:----4 STATE OF ALASKA OIL AND GAS CONSERVATION SUBMIT ~ DUPLICATE MONTHLY RE!PORT OF 'DRILLING AND WORKOVER OPERATIONS o,, ~] o,. © WELL W~.LL OTHER 2. NAME OF OPERATOR Union 0i1 Company of California* 3. AD/)RESS OF OPEl:LAiR 2805 Denali Street, Anchorage, Alaska 99503 4. LOCATiON O,F WELL Surface- 761.3' N, 1131.5' E from SW Corner, Sec. 6, TSN, .R13W, SM Top of Hemlock: 660' N, 660' E from SW Corner, Sec. 32, TgN, R13W, SM ~5. AP! NUAIERICAL ~ODE 50-]33-20]40 LEASE DESIGNATION AND SEi~IAL NO. ADL- 17594 ?, IF INDIA)~, ALOTTEE OR TRI'BE NAME 0, UNIT,FA.RA{ OR LEASE NAME Trading Bay Unit g. WET.L NO, D-l] (14-32) 10, I'IEI.,D A-ND POOL, OR WILDCAT McArthur River Field Sec. 32, TgN, R13W, SM 11. PERMIT NO. 68-73 13. REPORT TOTAL DEPTH AT END OF MONTH, CHA_N'GES IN HOLE SIZE, CASING ANT) CKNIENTING JOBS INCLUDING DEPTH SET AND VOL~ USED, PE-RFOP,~ATIONS. TESTS ANT) RESULTS, FISHING JOB~, JUNK IN HOLE A. ND SIDE-TRACKED HOLE AND A_NY OTH]ER SIGNIFICANT CHANGES IN HOL~ CONDITIONS. Tradinq Bay Unit D-11, October 1968 10/1 - 10/8 Drilled and surveyed 8-1/2" hole from 10,369' to 11,682'. hole to log. Conditioned 10/9 Rigged up SchlUmberger; ran DIL, Borehole Compensated Sonic, Formation Density, Dipmeter. Conditioned hole for liner. 10/10 - 10/11 Ran 7" 29 Lb N-80 X-Line Liner; used Baker Loc on skoe, collar and bottom 2 joints,' ran 4 centralizers on bottom 2 joints, one each on next 16 joints and 2 each on top 6 joints. Circulated one hour, set hanger., pumped 500 gallons mud sweep ahead; mixed 600 sacks Class G treated with 0.5% R-5 and 1% D-19 with fresh water. Bumped plug with 2000 psi; set packer and reversed out approximately 50 bbl cement. Cleaned out 9-5/8" casing to top of liner at 9440', ran 6" bit and 7" scraper; tagged top of liner at 9440 and PBTD at 11,425; circulated 2 hours, pressure tested liner lap to 2000 psi, held OK. Rigged up Schlumberger and ran Cement Bond Log and Gamma Correlation Log. 10/12 10/13 Drill stem test No. 1 liner lap with Baker model C full bore set down retrievable cementer. With 1000' fresh water cushion, set packer at 9420 with 5' tail; open 60 minutes, weak blow for 50 minutes and died. ,:i).~~red 20 ft mud with water cushion, charts indicated tool open *. :': ~'~ ~t~E' ho plugging. Rigged up Schlumberger and ran ring gauge. 32 lb AGT packer at 10,818'. Ran 48 joints 3-112" seal lock ,N~4tO~~S1 joints 4-]/2" seal lock tubing, tested tubing with 2000 psi, ~-;~~l 1/4" tubing w~ith 5000 psi, removed BOE and installed Xmas tree, tested tree with 5000 psi; tested 1/4" tubing 5000 psi. AGT packer at lO,Sll tubing meas; tail at 10,833'~ pulled dummy valve; landed tubing on AGT packer with 15,,00._0_p~_s.i_.._on~ p_a_.c~ker. , Form No. P--4 R3L'V. 9-30-61 STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE SUBMIT IN DUPLICATE MONTHLY RE!PORT OF DRILLING AND WORKOVER OPERATIONS ~5. AP1 NUS~ERICAL CODE 50-133-20140 6. LEASE DESIGNATION AXD SERIAL NO. ADL 17594 WELL WELT, OTHER 2. NAME OF OPERATOR Union Oil Company of California* 3. AD~'RESS OF' OPERATOR 2805 Denali Street, Anchoraqo, Alaska 99503 4. LOCATION OF WELL Surface: 761.3' N. 1131.5' E from SW Corner, Sec. 6, TSN, R13W, SM Top of Hemlock: 660' N, 660' E from ~SW corner, Sec. 32, TgN, R13W, SM 8. U'NIT,FARA{ OR LEASE NAME Trading Bay Unit 9. WEt. J_, NO. D-11 (14~32) 10. FIw. L,D A_ND POOL. OR WILDCAT McArthur Ri ver Fi el d 11. SEC., T., R., 1%{.. (BOl'FOI%{ HOLE OBJECrrVE) Sec. 32, T9N, R13W, SM 12. PEH/VIIT NO. 68-73 13. REPORT TOTAL DEPTH AT END OF MONTH, CHANGES IN HOLE SIZE, CASING AN-D CEMENTING JOBS INCLUDING DEPTH SET ~ VOLLrNIES USED, PERFOHATIONS, TESTS AND RESULTS. FISHING JOBS, JUI~K IN HOLE A.ND SIDE-TRACKED HOLE A~N-D ANY OTHER SIGNIFICANT CHANGES IN HOLE CONDITIONS. Trading Bay Unit D-.ll~ sept.1968, i,page 2 9/27 collar at 9604', centralizers located on bottom four joints, conditioned (Cont'd) mud for one hour, ran 500 gallons of mud sweep, followed by 2400 sacks Class G cement, mbjmnded with 8% gel, 0.5%R-5 and 0.8% D-31 mixed in 500 bbls seawater, followed by 200 sacks Class G cement mixed in fresh water, displaced with rig pumps and bumped plug with 3000 psi. Complete circula- tion maintained throughout the cementing operation, landed casing, installed pack off and tubing spool and tested well head. Installed BOP and riser, tested to 3000 psi, held OK. 9/28 Ran in with drilling assembly and drilled the float collar and cleaned out to 9670', tested casing at 2500', held OK, drilled out shoe at 9690', and drilled 8-1/2" hole to 9900'. 9/29-9/30 Drilled and surveyed 8-1/2" hole from 9930' to 10,369'. * Marathon Oil Company, Suboperator, Dolly Varden Platform. S~UN~n . ~ (B.E. Tallev~ Di~t. grlg. Su~t.. DA~ n-,nh~ lB; lqfiR I~OTE--Report/m this form is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the Division o~ Mines & Minerals by the 15th of the succeeding month, unless otherwise directed. Fo~ No. P--4 STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE SUBMIT IN' DUPLICAT~ MONTHLY REPORT OF 'DRILLING AND WORKOVER OPERATIONS 2. NAME OF OPERATOR Union Oil Company of California* 3. ADDRESS OF OPEI:t. ATOR 2805 Denali Street, Anchorage, Alaska 99503 4. LOCATION O,F W~,T~L Surface: 761.3' N, 1131.5' E from SW Corner Section 6, T8N, R13W, SM Top of Hemlock: 660' N, 660' E from SW Corner, Sec. 32, T9N, R13W, SM AP! NUA'IElq/cAL ~ODE ' 50-133'201~0 LEASE DESIGNATION A.N-D SEIqlAL NO. ADL 17594 T. IF INDIA]~, ALOTTEE OR TRIBE NAME 8. LrNIT,FAP~{ OR LEASE NANIE Trading Bay Unit 9. WELL NO. D-II (14-32) 10. FIELD AND POOL. OR WILDCAT McArthur River Field 11. SEC., T., R., M., (BO'I~'OM HOI~ OB, rgcTnrE) Sec. 32, TgN, R13W, SM 12. PER.MIT NO. 68-73 13. REPORT TOTAL DEPTH AT END oF MONTH, CHAMGF~ IN HOLE SIZE, CASING ~ CEMENTING JOBS INCLUDING DEPTH SET A_N-D VOLUMES USED, PER.FOP~TIONS, TESTS AND I:LESULTS. FISHING JOB,S, JU/NTK IINT HOLE AXqD SIDE-TRACKED HOLE A. ND A-NY OTHZgR SIGNIFICANT CI4.AAT.~F-,S IN HOL]~ CONDITIONS. Trading Bay Unit D-ll, August 1968 8/30 Moved to Slot #3, rigged up on D-ll, cleaned out piling to 400', rigged up and ran Sperry Sun Gyrosurvey. 8/31 Gyro survey at 375' indicated 0° 15 min. total displacement from center leg 6.38' N, 1.44' W. Spudded at ll-30 am 8-31-68. Drilled and surveyed 17-1/2" hole from 400' to 1025'. * Marathon Oil Company, Suboperator, Dolly Varden Platform mGmm B,~f ~ai:~e~,,, ... _. ~_~ Dist. Drl~. Suprtd. nA~.. 9/10/68 NOTE--Report on this fl 'm is required for each calendar month, regardless of the status of operations, and must be filecl in duplicate with the Division of Mines & Minerals by the 15th of the succeeding month, unless otherWise directed. FORM SA- I B 1:25.5M 8/67 MEMORANDUM TO:i- FROM: Sta.te ,of Alaska DATE : SUBJECT: FORM SA- lB 125.5M 8/67 MEMORANDUM TO: J-' FROM: State of Alaska DATE : SUBJECT~ Sir: Form P--1 REV. 9-30-67 SUBMIT IN TRIk~,~ATE (Other instructions on reverse side) STATE O'F ALASKA OIL AND, GAS CONSERVATION COMMITTEE APPLICATION FOR PERMIT TO DRILL, DEEPEN, OR PLUG BACK 1~. TYPE OF WORK b. TYPE OF WELL 0IL WELL __ DEEPEN [] DRILL ~ SINGLE OAS [__J OTHER ZONE WELL 2. NA1HE OF OPERATOR * Union 0il Company of Californ{a 3. ADDRESS (YF OPERATOR 2805 Denali Street, Anchorage, Alaska 99503 4. PLUG BACK [] MULTIPLE ~_~ ZONE LOCATION OF WELL Atsur£ace 761.3'N, 1131.5'E, from SW corner, Sec. 6, T8N, R13W, SM At proposed prod. zoneTop Hemlock - 660'N, 660'E from SW corner, Sec. 32, TgN, R13W, SM " 14. TYPE DISTANCE IN MILES AND DIRECTION F1OM NEAREST TOWN OR(POST OFFICE* 21 miles northwest of Kenai,-Alaska~ , BOND INFORMATION: Statewide United Pacific Insurance Co. B-55502 Surety and/or No. 15. DISTANCE FROM PROPOSED*' LOCATION TO NEAREST (Also to nearest drig, unit, if any) 1,000 ' ' 1~. DISTANCE FROM PROPOSED LOCATION* TO NEAREST WELL DRILLING. COMPLETED. OR APPLIED FOR, FT. 2,900' NO. OF 'ACRES IN LEASE pROp6SED'D~rH 1 , 720MD, 1~, ]~0.VD 21. ELEVATIONS (Show whether DF. RT, C-R, etc.) 116.00' R.T. MLLW 23. P~OPO.SED CASING AND C~W~ENTING PROGRAM'-' API 50-133-20140 6. LEA~E DE~iGNATION AND SERIAL NO. ADL 17594 7. IF INDIAN, ~LIJ~O~I'EE OR ~RIBE N~ UNiTFARM OR LEASE NAME 8. Tradi.ng Bay Unit 9. WELL NO. D-il (14-32) 10. FIELD AND POOL, OaK WILDCAT McArthur River Field-Hemlock 11. SEC.-, T., R., M., (BOTTOiVI HOLE OBJECTIVE) Sec. 32, T9N, R13W, SM 12. ~o..~ $100,000.00 I?.,-N-O. ACI~ES ASSIGNED TO THiS WELL 160 ROTARY OR CABLE TOOLS ~i~Rot ar¥ 22. APPROX.. DATE WORK WILL START* .: S~ptember 15, 1968 SIZE OF HOLE SIZE OF CASINGS[, WEIGHT PER FOOT GRAD~ ~i '~'~ '~E~TING DEP~-I: .... ~'- "- - : ~';" 17~ 13-5/8" I ] 61~ 3-55 2,500 2,400": saCk's 12~ 9-5/8" 40.43.5.47 N-80 9.700 .~.. 2.600 8~ 7,, 29~ N,.80 11.7~0 .800 ,, .... , , . .-~ : · .. ', .. - , ~.... Install 20" Hydril and 20" riser. Drill t2¼" hole to approximately. 2,500'. Open 12¼" hole to 17½". Run and cement 1.3-3/8" casing. Ins'tall 12" 5,000#. ~BOPE, Test to 3,000#. Test 13-3/8" casing to 2,000#. Drill 12¼" hole to approximately 9,7. ' 0.0.. Run and cement 9-5/8" casing. Install and test BOPE to 3,000#. Test 9-5/8" casing to 2,000#. Drill 8½" hole to TD. Run and cement 7" liner. Test line~,, ~comp-tete for~production with 4½" tubing. " - :-~ :~ ' ~ .... -: ~ Bottom Hole Location - 989' from S line, 687' from W line, Sec.32, T9N, R1SW, SM Marathon Oil Company - Suboperator - Dolly Varden Platform IN ABOVE SPACE DESCRIBE PROPOSED PROGRAiFi: If proposal is to deepen or plug back, give data on present productive zone and proposed new productive zof~e. If proposal is to drill or deepen directlonally, give pertinent data on subsurface locations and measu~d and true vertical depths. Give blowout preventer program. hereb~re~d;' .~e ?~k~°rre~F -// ace ~or S~te office u~) CONDm6NS OF ~PROV~, IF ~: ~ SA~L~S AND CO~ C~PS REQUI~ ] ~ ~U~TS: l DI~C~ON~ SURVEY ~~ [ A.P.L ~C~ CODE XaTLE District l.snd Mnnager APPROVED BY_~/~ ~~~ 'TITLE, ' E;:cc,Jtbf* g~cratarv '7'd, o ' ~':-:).", <:. <:/~ ..... _? ~f,.., ~_ ~ See In~ucti°ns On R~e~e ~d~ Gas /' /-; ~ ~nservotion ~i~ D~T~ 8- 23 - & ~ o D-II (14-32) D-I PBHL 0 (54-52) TMD 11,720' ~ ,X~ TVD 10,120' ~ Prop, Top Hemlock TMD I1~000' ADL 17594 ~vo 9,5bo~ ./ I ' ' I / I /, UNION-MARATHON DOLLY VA.RDEN' --D-5 ./ q- D-7 ..0 (14-33) D-2 (22-5) TgN I ,. ! ~ ,, ' T8 N 8 lTD 11,281' "'"'°~,oE' D-4 --'(24-5) ......... "0~D-9 .':'0 D-12 (~t~-7) ~ (22- 8) J~ D-lO (44-5) "',, D-8 (;:'4-8) 0 U-M ADL 187.29 l PPSS ADL 17579 ~-- J¥ UNION R 13W RISW N WELL LOCATION-MAP' : MARATHON SUB-OPERATOR'- TRADING BAY STATE D-I/ (14-:52) o 2000 .