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Home My WebLink About167-080STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon ❑ Repair Well ❑ Plug Perforations ❑ Perforate ❑ Other Lij Scale Removal Performed: Alter Casing ❑ Pull Tubing❑ Stimulate - Frac ❑ Waiver ❑ Time Extension Change Approved Program ❑ Operat. Shutdown❑ Stimulate - Other F] Re-enter Suspended Well 2. Operator 4. Well Class Before Work: 5. Permit to Drill Number: Name: Hilcorp Alaska, LLC Development F] Exploratory ❑ Stratigraphic❑ Service ❑ 167-080 3. Address: 3800 Centerpoint Drive, Suite 1400 6. API Number: Anchorage, AK 99503 50-733-20068-00 7. Property Designation (Lease Number): 8. Well Name and Number: ADL0017594 Trading Bay Unit / D-01 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pool(s): McArthur River Field / Hemlock Oil and Middle Kenai G Oil Pools 11. Present Well Condition Summary: I V Total Depth measured 12,071 feet Plugs measured N/A feet true vertical 9,798 feet Junk measured 11,497 (fill) feet DEC 0 12014 Effective Depth measured 11,497 feet Packer measured N/A feet®��^ true vertical 9,365 feet true vertical N/A feet Casing Length Size MD TVD Burst Collapse Structural Conductor 716' 20" 716' 716' 1,530 psi 520 psi Surface 2,527' 13-3/8" 2,527' 2,430' 3,090 psi 1,540 psi Intermediate 9,690' 9-5/8" 9,690' 7,945' 5,750 psi 3,090 psi Production Liner 2,494' 7" 12,063' 9,792' 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) 4-1/2" 12.6# / L-80 8,552' (MD) 7,079' (TVD) Packers and SSSV (type, measured and true vertical depth) N/A 12. Stimulation or cement squeeze summary: Intervals treated (measured): 10,370'- 11,497' SCA00DEC 15 2014 Treatment descriptions including volumes used and final pressure: See attached operations summary 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf I Water -Bbl I Casing Pressure Tubing Pressure Prior to well operation: 173 681 6975 114 120 Subsequent to operation: 0 01 01 1100 868 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run Exploratory❑ DevelopmentE Service ❑ Stratigraphic ❑ Daily Report of Well Operations X 16. Well Status after work: Oil E 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: 1314-557 Contact Dan Marlowe Email dmarlowe(a)-hilcorp.com Printed Name Dan Marlowe Title Operations Engineer Signature Phone (907) 283-1329 Date 12/1/2014 Iz _/Z_ -l'Y RBC 1�S PL Form 10-404 Revised 10/2012 Submit Original Only~~r Trading Bay Unit SCHEMATIC Well: D-01 J3.►�rp Alaska, LLc As Completed: 07-07-2014 RKB = 39.10' Rig Floor to DCB TBG Spool 20" DV Tool 5,856' Top Liner 9,569' G-2 19 G-3 G-4 B-1 B-2 TOF @ 11,497'B-3 B-4 B-5 Fish @ 11,849' MWEWB-6 ® :7„ TD =12,071'/ PBTD 11,998' ETD = 11,849' 44.3 deg @ 3,900' CASING DETAIL Size WT Grade Conn ID Top B m Hole Cmt Tot 20" 94# H-40 8 rd 19.124 Surface 716' 26" 1,600 sxs Surface 13-3/8" 61# J-55 Butt 12.515 Surface 2,527' 17 %" 2,100 sxs Surface 6 SPF, 60 -deg+ PJ Omega Reperf 2/07 40# N-80 Butt 8.835 Surface 4,860' 25'5 SPF, 4-1/2" PJ Omega (2/21/07) B-1 11,250' 43.5# N-80 Butt 8.875 4,860' 6,315' 12/1/2004 2,066 sxs Surface 9-5/8" 47# N-80 Butt 8.681 6,315' 8,772' 11,435' 11,495' 9,318' 9,363' 47# P-110 Butt 8.681 8,772' 9,690' 9,379' 9,497' 155' 6 SPF, 60 deg B-5 11,695' 11,850' LINER DETAIL 9,633' 155' 120 -deg phasing 7" 29# N-80 X -Line 1 9,569' 1 12,063' 8-1/2" 820 sxs 9,569' TUBING DETAIL 4.5" 12.6# L-80 Hydril 563 SCC 3.908" Surface 8,552' JEWELRY DETAIL No Depth ID Item 1 8,552' Head Bolt on Discharge 2 8,553' Pump (0) 3 8,607' Intake 4 8,626' Motor (x2) 5 8,690' Bottom of ESP Assembly FISH IN WELL: 1989: 4-1/2" TCP Gun Bull Plug = OD ?, .75" long. 6-19-1998: Schlumberger pert gun: 1- 3/8"x19" MH -22, 1-11/16"x21" CCL, 2-1/8"x19.5" MPD, 2-1/2x42,5" Safe system, 2-1/2'x20' HC pert gun (fired), 2-1/2"x2' bull plug. = 31.8' total length (Top 11,849 (+/-). 2007 ESP WO- Cleaned out wellbore to 11,508' Reperfed G zone PERFORATION DETAILS Zone Top(MD) Bottom(MD) Top(TVD) Bottom(TVD) Length Condition G-2 10,730' 10,755' 8,764' 8,784' 25' 6 SPF, 60 -deg+ PJ Omega Reperf 2/07 G-3 10,795' 10,825' 8,816' 8,840' 30' 6 SPF, 60 -deg + PJ Omega Reperf 2/07 G-4 10,848' 10,890' 8,859' 8,892' 42' 6 SPF, 60 -deg+ PJ Omega Reperf 2/07 G-4 10,893' 10,918' 8,894' 8,914' 25'5 SPF, 4-1/2" PJ Omega (2/21/07) B-1 11,250' 11,300' 9,175' 9,214' 50' 6 SPF, 60 deg B-2 11,320' 11,410' 9,229' 9,299' 90' Squeezed B-3 11,435' 11,495' 9,318' 9,363' 60' 6 SPF, 60 deg B-4 11,515' 11,670' 9,379' 9,497' 155' 6 SPF, 60 deg B-5 11,695' 11,850' 9,516' 9,633' 155' 120 -deg phasing B-6 11,865' 11,930' 9,644' 9,693' 65' 120 -deg phasing Updated by: JLL07/07/14 ROTATING HOURS 28" Drive Pipe - 37 hrs 20" Casing 50.5 hrs 13-3/8" Casing - 275.5 hrs 9-5/8" Casing 246.5 hrs 7" Casing 73.5 hrs Updated by: JLL07/07/14 Hilcorp Alaska LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date D-01 50-733-20068-00 1 167-080 10/22/14 11/1/14 Daily Operations: 10/22//14 - Wednesday Pressure tested surface lines to 2000 PSI. Ensured tote was grounded to the tank. Filled casing with 142BBLs, on vacuum, 4.5 BPM caught fluid @ 11:40. Pump 10BBLs. Injectivity test @ 120# 9 5/8 csg. Waterflood problems. Back working at 18:00. Pumped pre flush of 330 gallons WAW-5206 and 660 gallons xylene @ 2.3 BPM at 0 PSI 56BBLs. Started acid, 71BBLS 7.5% HCL acid away 13 PSI at 2.4BPM, 95BBLS total acid. Started FIW 50 PSI at 4.7 BPM, 100BBLs away FIW 325 PSI and 2.1 BPM. 380 PSI at 2.1 BPM, 150BBLs FIW away. End of job, 200BBLs FIW away 460 PSI at 2.1 BPM, 6HR soak, returned to production. 11/01/14-Saturday PSI Test @ 90# Low 500# Low 2000# High= All Good. Filling Up Back Side @ 4.3 BPM T&C 9 5/8 =6 PSI. Caught fluid on back side - 134 Bbls FIW with Casing pressure @150#. Begin Pumping Acid @ 2.1 BPM Rate @ 125#. 40 Bbl Acid Away 1.93 BPM @ 206# T&C. 65 Bbl Acid Away 1.97 BPM @ 227# Tubing & CSG 9 5/8. Total of 4500 gallons 15% HCL pumped. Displaced w/ 200 Bbl FIW at 1.1 BPM @ 1.8 PSI. Rigged Down Hoses. Blew Out Pump. Shut well in for 6 Hour Soak and returned to production. THE STATE 77 GOVERNOR SEAN PARNELL Dan Marlowe Operations Engineer Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 tG-t _ a%o Alaska 041 and Gas 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 Re: McArthur River Field, Hemlock Oil and Middle Kenai G Oil Pools, TBU D-01 Sundry Number: 314-557 Dear Mr. Marlowe: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. DATED this L-�dla y of October, 2014. Encl. Sincerely, Cathy P Foerster Chair SCANNED 0CT 2 2 2014 STATE OF ALASKA D5tA ALASKA OIL AND GAS CONSERVATION COMMISSION (o11('114 APPLICATION FOR SUNDRY APPROVALS 20 AAC 25 280 RECEIVED OCT 13 2014 VC5 lal15//4-- A0GG0 1. Type of Request: Abandor ❑ Plug for Redril' ❑ Perforate New Pool ❑ Repair Well ❑ Change Approved Program ❑ Suspenc ❑ Plug Perforations ❑ Perforate ❑ Pull Tubing ❑ Time Extension ❑ Operations Shutdowr ❑ Re-enter Susp. Wel ❑ (-: Stimulate 0 Alter Casing ❑ Other: 2. Operator Name: 4. Current Well Gass: 5. Permit to Drill Number: Hilcorp Alaska, LLC Exploratory ❑ Development Q Stratigraphic ❑ Service ❑ 167-080 3. Address: 3800 Centerpoint Drive, Suite 1400 6. API Number. Anchorage, AK 99503 50-733-20068-00 /U. 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? N/A Will planned perforations require a spacing exception? Yes ❑ No ❑ Trading Bay Unit ! D-01 9. Property Designation (Lease Number): 10. Field/Pool(s): ADL0017594 I McArthur River Field / Hemlock Oil & Middle Kenai G Oil Pools 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 12,071 9,798 11,497 9,365 N/A 11,497 (fill) " Casing Length Size MD TVD Burst Collapse Structural Conductor 716' 20" 716' 716' 1,530 psi 520 psi Surface 2,527' 13-3/8" 2,527' 2,430' 3,090 psi 1,540 psi Intermediate 9,690' 9-5/8" 9,690' 7,945' 5,750 psi 3,090 psi Production Liner 2,494' 7" 12,063' 9,792' 8,160 psi 7,020 psi Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): See Schematic See Schematic 4-1/2" 12.6# / L-80 8,552 Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): N/A N/A 12. Attachments: Description Summary of Proposal PTI 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch Q Exploratory ❑ Stratigraphic ❑ Development Q Service ❑ 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: 10/15/2014 Oil E1 Gas ❑ WINJ E]GINJ ❑ WDSPL ❑ Suspended ❑ WAG ElAbandoned ❑ 16. Verbal Approval: Date: Commission Representative: GSTOR ElSPLUG El 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Dan Marlowe Email dmarlowe(d-Wlcorp.com Printed Name Dan Marlowe Title Operations Engineer Signature Phone (907) 283-1329 Date 10/13/2014 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: /0 — yb Y APPROVED BY Approved by: �y (wJ COMMISSIONER THE COMMISSION Date: l yc I o -v aIIGIXr.ALnthsI -aria �opj//� '0101„1yeySubmit Form and Form 10-403 (Revised 10/2012) Approfrom the date of approval. Attachments in Duplicate FIV OCT 2 01 Hilcoru Alaska, M Well Work Plan Well: D-01 Date:10/11/2014 Well Name: D-01 API Number: 50-733-20068-00 Current Status: ESP Lifted Producer Leg: Leg # A-2 (northwest) Estimated Start Date: October 15, 2014 Rig: N/A Reg. Approval Req'd? Date Reg. Approval Rec'vd: Regulatory Contact: Juanita Lovett Permit to Drill Number: 167-080 First Call Engineer: Dan Marlowe (907) 283-1329 (0) (907) 398-9904 (M) Second Call Engineer: Ted Kramer (907) 777-8420 (0) (985) 867-0665 (M) AFE Number: Budgeted Cost: Current Bottom Hole Pressure: -2,500 psi @ 7,198' TVD Current pressure measured from down -hole gauge Maximum Expected BHP: -3,841 psi @ 9,327' TVD No new perfs Max. Allowable Surface Pressure: 2,000 psi Max pump pressure Well Summary This well was worked over to replace the ESP July 07, 2014. During a production shutdown October 11, 2014, the well experienced a loss of inflow due to a suspected scale bridge. This acid job is intended to restore productivity. Procedure - 1. MIRU pumping equipment. 2. Shutdown ESP. 3. Pressure test surface lines to 2,000 psi. 4. Mix chemicals and pump in the following sequence: a. Open backside, pump FIW down tubing until returns are received up the annulus. (Volume to bottom of the pump inside of tubing is 142 bbls. Vol. of Annulus to bottom of the pump is 499 bbls.) b. Pump 24 bbls of prefIush(Consisting of 330 (+/-) gals. of WAW -5206 and 660 gals of Xylene from the mix tank). c. Pump 95.23 l3bls. (+/-) 7-1/2% HCL (4,000 gals) d. Close the 9-5/8" casing reFurn i e - e. Displace with 200 bbls FIW. f. Soak for 6 hours 5. Return to production. 6. Schedule a no -flow within 14 days of stabilized production. Attachments: 1. As -built Schematic ' SCHEMATIC Trading Bay Unit Well: D-01 �llileorp Alaska, LLC As Completed: 07-07-2014 RKB = 39.10' Rig Floor to DCB CASING DETAIL TBG Spool 20" DV Tool 5,856' Top Liner 9,569' G-2 G-3 G-4 H-AA-:TOF B-1 B-2 @ 11,497'B -3B-4 B-5 Fish @ 11,849' IMOVEWB-6 - 7„ TD =12,071'/ PBTD 11,998' ETD = 11,849' 44.3 deg @ 3,900' Size WT Grade Conn ID Topp Btm Hole Cmt Top 20" 94# H-40 8 rd 19.124 Surface 716' 26" 1,600 sxs Surface 13-3/8" 61# J-55 Butt 12.515 Surface 2,527' 17 %" 2,100 sxs Surface 6 SPF, 60 -deg + PJ Omega 40# N-80 Butt 8.835 Surface 4,860' Reperf 2/07 G-4 10,848' 43.5# N-80 Butt 8.875 4,860' 6,315' 12/1/2004 2,066 sxs Surface 9-5/8- 47# N-80 Butt 8.681 6,315' 8,772' 10,893' 10,918' 8,894' 8,914' 47# P-110 Butt 8.681 1 8,772' 9,690' B-1 11,250' 11,300' LINER DETAIL 9,214' 50' 6 SPF, 60 deg 7" 29# N-80 X -Line 1 9,569' 1 12,063' 8-1/2" 820 sxs 9,569' 11,495' 9,318' 9,363' 60' TUBING DETAIL B-4 11,515' 11,670' 9,379' 4.5" 12.6# L-80 Hydril 563 SCC 3.908" Surface 8,552' 9,633' 155' 120 -deg phasing JEWELRY DETAIL No Depth ID Item 1 8,552' Head Bolt on Discharge 2 8,553' Pump (x3) 3 8,607' Intake 4 8,626' Motor (x2) 5 8,690' Bottom of ESP Assembly FISH IN WELL: 1989: 4-1/2" TCP Gun Bull Plug = OD ?, .75" long. 6-19-1998: Schlumberger pert gun: 1- 3/8"x19" MH -22, 1-11/16"x21" CCL, 2-1/8"x19.5" MPD, 2-1/2x42,5" Safe system, 2-1/2"x20' HC perf gun (fired), 2-1/2"x2" bull plug. = 31.8' total length (Top 11,849 (+/-). 2007 ESP WO- Cleaned out wellbore to 11,508' Reperfed G zone PERFORATION DETAILS Zone Top(MD) Bottom(MD) Top(TVD) Bottom(TVD) Length Condition G-2 10,730' 10,755' 8,764' 8,784' 25' 6 SPF, 60 -deg+ PJ Omega Reperf 2/07 G-3 10,795' 10,825' 8,816' 8,840' 30' 6 SPF, 60 -deg + PJ Omega Reperf 2/07 G-4 10,848' 10,890' 8,859' 8,892' 42' 6 SPF, 60 -deg + PJ Omega Reperf 2/07 G-4 10,893' 10,918' 8,894' 8,914' 25' 5 SPF, 4-1/2" PJ Omega(2/21/07) B-1 11,250' 11,300' 9,175' 9,214' 50' 6 SPF, 60 deg B-2 11,320' 11,410' 9,229' 9,299' 90' Squeezed B-3 11,435' 11,495' 9,318' 9,363' 60' 6 SPF, 60 deg B-4 11,515' 11,670' 9,379' 9,497' 155' 6 SPF, 60 deg B-5 11,695' 11,850' 9,516' 9,633' 155' 120 -deg phasing B-6 11,865' 11,930' 9,644' 9,693' 65' 120 -deg phasing Updated by: JLL07/07/14 ROTATING HOURS 28" Drive Pipe 37 hrs 20" Casing 50.5 hrs 13-3/8" Casing - 275.5 hrs 9-5/8" Casing 246.5 hrs 7" Casing 73.5 hrs Updated by: JLL07/07/14 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon ❑ Repair Well ❑ Plug Perforations ❑ Perforate ❑ Other ❑s Replaced ESP Performed: Alter Casing ❑ Pull Tubing❑ Stimulate - Frac ❑ Waiver ❑ Time Extension[] Change Approved Program ❑ Operat. Shutdown❑ Stimulate - Other ❑ Re-enter Suspended Well E] 2. Operator 4. Well Class Before Work: 5. Permit to Drill Number: Name: Hilcorp Alaska, LLC Development R] Exploratory ❑ Stratigraphic❑ Service ❑ 167-080 3. Address: 3800 Centerpoint Drive, Suite 1400 6. API Number: Anchorage, AK 99503 50-733-20068-00 7. Property Designation (Lease Number): 8. Well Name and Number: ADL0017594 Trading Bay Unit / D-01 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pool(s): McArthur River Field / Hemlock Oil and Middle Kenai G Oil Pools 11. Present Well Condition Summary: RECEIVE E w(v- E ■ ` - E 6 V Total Depth measured 12,071 feet Plugs measured N/A feet true vertical 9,798 feet Junk measured 11,497 (fill) feet JUL 0 7 2014 Effective Depth measured 11,497 feet Packer measured N/A feet A0G�C true vertical 9,365 feet true vertical N/A feet Casing Length Size MD TVD Burst Collapse Structural Conductor 716' 20" 716' 716' 1,530 psi 520 psi Surface 2,527' 13-3/8" 2,527' 2,430' 3,090 psi 1,540 psi Intermediate 9,690' 9-5/8" 9,690' 7,945' 5,750 psi 3,090 psi Production Liner 2,494' 7" 12,063' 9,792' 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) 4-1/2" 12.6# / L-80 8,552' (MD) 7,079' (TVD) Packers and SSSV (type, measured and true vertical depth) N/A 12. Stimulation or cement squeeze summary: Intervals treated (measured): 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: 138 22 10364 111 138 Subsequent to operation: 126 29 9019 120 112 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run Exploratory[] DevelopmentE] Service ❑ Stratigraphic ❑ Daily Report of Well Operations X 16. Well Status after work: Oil [21 Gas ❑ WDSPL❑ IGSTOR ❑ 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: 1314-294 Contact Dan Marlowe Email dmarlowe(c)_hilcorp.com Printed Name Dan Marlowe Title Operations Engineer Signature Phone (907) 283-1329 Form 10-404 Revised 10/2012 6 1.1 I 1 Submit Original Only -a SCHEMATIC Trading Bay Unit Well: D-01 tnl��„ alashu. �u As Completed: Sept. 20, 2012 RKB = 39.10' Rig Floor to DCB CASING DETAIL TBG Spool 20" DV Tool 5,856' Top Liner 9,569' 9-5/8" :.q.. G-2 G-3 G-4 +. B-1 B-2 TOF @ 11,497' �p B-3 B-4 B-5 Fish @ 11,849' B-6 - 7„ TD =12,071'/ PBTD 11,998' ETD = 11,849' 44.3 deg @ 3,900' Size WT Grade Conn ID Top Top gtm Hole Cmt To t p 20" 94# H-40 8 rd 19.124 Surface 716' 26" 1,600 sxs Surface 13-3/8" 61# J-55 Butt 12.515 Surface 2,527' 17%" 2,100 sxs Surface 6 SPF, 60 -deg + PJ Omega 40# N-80 Butt 8.835 1 Surface 4,860' Reperf 2/07 G-4 10,848' 43.5# N-80 Butt 8.875 4,860' 6,315' 12/1/2004 2,066 sxs Surface 9-5/8" 47# N-80 Butt 8.681 6,315' 8,772' 10,893' 10,918' 8,894' 8,914' 47# P-110 Butt 8.681 8,772' 9,690' B-1 11,250' 11,300' LINER DETAIL 9,214' 50' 6 SPF, 60 deg 7" 29# N-80 I X -Line 1 9,569' 1 12,063' 8-1/2" 1 820 sxs 1 9,569' 11,495' 9,318' 9,363' 60' TUBING DETAIL B-4 11,515' 11,670' 4.5" 12.6# L-80 Hydril 563 SCC 3.908" Surface 8,552' 9,516' 9,633' 155' JEWELRY DETAIL No Depth ID Item 1 8,552' Head Bolt on Discharge 2 8,553' Pump (0) 3 8,607' Intake 4 8,626' Motor (x2) 5 8,690' Bottom of ESP Assembly FISH IN WELL: 1989: 4-1/2" TCP Gun Bull Plug = OD ?, .75" long. 6-19-1998: Schlumberger perf gun: 1- 3/8"x19" MH -22, 1-11/16"x21" CCL, 2-1/8"x19.5" MPD, 2-1/2x42,5" Safe system, 2-1/2"x20' HC perf gun (fired), 2-1/2"x2" bull plug. = 31.8' total length (Top 11,849 (+/-). 2007 ESP WC- Cleaned out wellbore to 11,508' Reperfed G zone PERFORATION DETAILS Zone Top(MD) Bottom(MD) Top(TVD) Bottom(TVD) Length Condition G-2 10,730' 10,755' 8,764' 8,784' 25' 6 SPF, 60 -deg+ PJ Omega Reperf 2/07 G-3 10,795' 10,825' 8,816' 8,840' 30' 6 SPF, 60 -deg + PJ Omega Reperf 2/07 G-4 10,848' 10,890' 8,859' 8,892' 42' 6 SPF, 60 -deg + PJ Omega Reperf 2/07 G-4 10,893' 10,918' 8,894' 8,914' 25' 5 SPF, 4-1/2" PJ Omega(2/21/07) B-1 11,250' 11,300' 9,175' 9,214' 50' 6 SPF, 60 deg B-2 11,320' 11,410' 9,229' 9,299' 90' Squeezed B-3 11,435' 11,495' 9,318' 9,363' 60' 6 SPF, 60 deg B-4 11,515' 11,670' 9,379' 9,497' 155' 6 SPF, 60 deg B-5 11,695' 11,850' 9,516' 9,633' 155' 120 -deg phasing B-6 11,865' 11,930' 9,644' 9,693' 65' 120 -deg phasing Updated by: JLL07/07/14 ROTATING HOURS 28" Drive Pipe - 37 hrs 20" Casing 50.5 hrs 13-3/8" Casing - 275.5 hrs 9-5/8" Casing 246.5 hrs 7" Casing 73.5 hrs Updated by: JLL07/07/14 Hilcorp Alaska, LLC HilcorpAla,k.,.LLC Well Operations Summary Well Name JAPI Number lWell Permit Number Start Date End Date D-01 50-733-20068-00 167-080 5/31/2014 6/7/2014 Daily Operations: 05/31/14 -Saturday RIGGING UP. 06/01/14 -Sunday N/D PRODUCTION TREE. N/U 11" X 5M BOPS, 11" RISER, SPACER SPOOLS, CHOKE & KILL WING VALVES. HOOK-UP KOOMEY LINES, PRESSURE UP ACCUMALATOR & FUNCTION SAME. INSTALLED POLLUTION PANS UNDER RIG FLOOR, FLOOR BEAMS & PLATE. SECURED STACK AND BARRICADES AROUND BOPS. P/U 4-1/2" TEST ASSY & M/U TO HGR. R/U TEST EQUIPMENT. TEST 11" X 5M BOPS & SURFACE EQUIP AS PER AOGCC & HILCORP SPECS 250 LOW / 2500 HIGH ON CHART. WITNESS OF TEST WAIVED BY JIM REGG, AOGCC. TESTED FROM REMOTE & FUNCTION MAIN. R/D TEST EQUIP & PULL 2 -WAY CHECK VALVE. M/U LANDING JNT TO HGR. CIRCULATE GAS HEAD OUT OF WELL. 06/02/14 - Monday SERVICE RIG AND SAFETY COMPLIANCE CHECK. ASSIST CAMERON REP BACK OUT HGR PINS, PULL HGR TO RIG FLOOR. PUMP 100 BBLS 8.511 F.I.W DOWN CASING AT 3 BPM. CAMERON AND SCHLUMBERGER REP TERMINATE CONTROL LINE AND ELECTRICAL CABLE FROM HGR. BREAK OUT HGR AND LANDING JT, LAYDOWN SAME. POOH SLOW WITH 120' OF 4-1/2" PRODUCTION TBG, ELECTRICAL CABLE, CONTROL LINE & ESP PUMP. PRESSURE WASH AND CLEANING SAME. RUN ELECTRICAL AND CONTROL LINES THRU SHEAVES AND HANG SAME IN DERRICK. CONT POOH SLOW WITH 4-1/2 PRODUCTION TBG, ELECTRICAL CABLE, CONTROL LINE & ESP PUMP. PRESSURE WASH AND CLEANING SAME. SERVICE RIG AND SAFETY COMPLIANCE CHECK. CONT POOH SLOW WITH 4-1/2" PRODUCTION TBG, ELECTRICAL CABLE, CONTROL LINE & ESP. PRESSURE WASH/CLEAN SAME. ASSIST SLB REP CUT POWER CABLE & SWAP SPOOL. CONT POOH SLOW WITH 4-1/2" PRODUCTION TBG, ELECTRICAL CABLE, CONTROL LINE & ESP. PRESSURE WASH/CLEAN SAME. 7000' OUT OF HOLE. TOTAL FLUID LOSS=300 BBLS 06/03/14 -Tuesday NT POOH SLOW W/4-1/2" PROD TBG CONTROL LINE ELECTRICAL CABLE AND ESP PUMP. PRESSURE WASH/CLEAN SAME. SCHLUMBERGER TERMINATE CONTROL LINE AND ELECTRICAL CABLE FROM ESP PUMP. CONT POOH W/ESP ASSY AND LAY DOWN SAME. REMOVE HANDLING TOOLS FROM RIG FLOOR & REMOVE SHEAVES FROM DERRICK. WASH AND CLEAN RIG FLOOR. PREP RIG FLOOR TO RIG UP E -LINE. SPOT SUMMIT EQUIP & SPOOLS WHILE WAITING ON EXPRO EQUIP TO ARRIVE. N/U ADAPTER FLANGE FOR LUBRICATOR. R/U WIRE -LINE EQUIP. & LUBRICATOR. TEST SAME TO 2500 PSI. P/U 2.75" CALIPER LOG & 1-11/16" GR. RIH W/SAME TO 9214' WLM UNABLE TO GO DEEPER. POOH AND LOG F/9214'- T/7216' WLM WHEN LOST COMMUNICATION. CONT' POOH. WHEN TOOL AT SURFACE FOUND 15' SECTION OF DAMAGED WIRE. ATTEMPT TO RETRIEVE TOOLS FROM WELL WHEN WIRE PULLED OUT OF ROPE SOCKET AND LOST WIRE -LINE TOOLS. PERFORM GENERAL HOUSEKEEPING AND MAINTENANCE AROUND RIG WHILE WAITING ON W/L FISHING TOOLS & BRAIDED LINE UNIT TO ARRIVE LOCATION. 06/04/14 - Wednesday PERFORM GENERAL RIG MAINTANCE WHILE WAITING FOR BRAIDED LINE UNIT AND FISHING TOOLS TO ARRIVE. HELD PREJOB JSA. R/U EXPRO UNIT & LUBRICATOR, TST SAME TO 250 LOW 2500 HIGH. RIH WITH 4-1/2" OD LIB 5822' AND TAGGED UP, POOH. RIH WITH 5-3/4" OVERSHOT ON 3" GS PULLING TOOL, BUMPED UP AT 5822'. CHASED FISH DOWN HOLE TO 9172', LATCHED FISH, ATTEMPTED TO JAR SAME FREE AND SHEARED PULLING TOOL. POOH WITH SAME, REDRESS PULLING TOOL. RIH WITH 3" GS PULLING TOOL, LATCH FISH @ 9180' ATTEMPTED TO JAR SAME FREE AND SHEARED PULLING TOOL AGAIN. POOH WITH SAME, REDRESS 3" GS RIH WITH SAME LATCHED FISH AT 9180' JARRED SAME FREE & POOH. B/O & L/O WIRELINE FISHING TOOLS AND CASING CALIBER TOOLS. P/U & M/U 4-1/2" GAUGE AND RIH WITH SAME TO 9187'& TAGGED UP. UNABLE TO WORK DEEPER, POOH WITH SAME & R/D SLICKLINE. Hilcorp Alaska, LLC Ilileorp Alaska, LLC Well Operations Summary Well Name JAPI Number 1well Permit Number iStart Date End Date D-01 50-733-20068-00 167-080 1 5/31/2014 6/7/2014 Daily Operations: 06/05/14 -Thursday R/d E/line equipment. R/d lubricator head and flange. Pump 270 stks/10 bbls Filtered Inlet seawater down annulus. R/u Summit to run ESP. Pump 270 stks/10 bbls Filtered Inlet seawater down annulus. Held JSA Safety meeting. Start hanging sheaves in derrick for ESP cable and chemical injection lines. Finish hanging sheaves in derrick. Pump 270 stks/10 bbls Filtered Inlet seawater down annulus. Changed out elevator to 3-1/2" for Summit lift sub. Pump 270 stks/10 bbls Filtered Inlet seawater down annulus. P/u 2 pump sections and fill with oil to displace air with oil. M/u electric connection on ESP. Pump 270 stks/10 bbls Filtered Inlet seawater down annulus. Continue m/u ESP pump according to Summit Rep. P/u middle section. Install discharge head and control line. M/u crossover to tubing 4.5" 563 Hydril. P/u one stand and test ESP pump, Good Test. Held a cable cutting drill for all Rig floor crew. Continue tih with pump installing cable clamps every other connection. 1000' in hole conduct test on cable, Continue tih with esp testing electric cable. 2139' in hole. 06/06/14 - Friday Held Cable cutting drill with rig crew. Tih with ESP drifting and tallying each stand from derrick. Installing canon clamps as per Summit Rep. preforming continuity test on cable and chemical injection lines every 1000 ft. Change out spools and preform splicing of cable 5167' in hole. Continue tih w/4.5" 563 Hydril Tubing and ESP Pump. Install Cannon Clamps on every other tool joint. Testing cable every 1000' as per Summit rep. On joint 210 clamp hung up on slips, damaging armor, repair armor and test cable Good Test continue tih. Continue tih hole. Bottom of pump at 8648.71'. Total depth of tubing in hole 8508.68'. M/u pups and hanger and splice cable. 06/07/14 - Saturday Assist Summit Rep make splice on hanger connection. Make up Landing Joint and remove air slips. Tie ESP power cable into hanger and Cameron rep tie chemical injection line into hanger. Test same to 1000 psi Good Test. Land Hanger. Picl� up Weight: 132,000 #. Slack off Weight# 82,000 #. Block Weight 8,000 #. Assist Cameron to run in hanger pins, rig down landing joint and remove Summit sheaves from derrick. Assist Cameron with installing BPV in tubing hanger. Nipple down 11" 5m stack, pull riser and lay out with crane. Prep wellhead and install tree. Tighten bolts to spec and assist with installing production flow line. Pressure test void to 5000 psi, Good Test. Pull 2 -way check. Pressure test production tree to 5,000 psi, Good Test. Install Electrical Stinger to production tree and connect control line. Prep to run ESP. Start cleaning well bay area and preform general maintenance. Summit testing surface electrical equipment and lines. Start up ESP Test Run. Continue house keeping and maintenance rig. Rig down. ➢:.' f�_;_a_-:aar!':.3' iai: ^39iv spa*.s tt- -sar ....': ... r-,:rror.w re-. ... ;:v -,' b.: e '<?d5+� a 1 ��P 7\\I//\ 4 E S T ATE �H 1, a 1,, - 1-. -y a 4 , yy (/ r 333 1ties+ Se\,en;h Avenue `a" _� Gov SFIAN i) 4I2N1:1_4.. Anchorace, Alaska 99501 35/2 ft aV up, � k Mair, 907.279 'c33 %MINE© MAY 1 6 2,014 Dan Marlowe Operations Engineer Hilcorp Alaska, LLC 1 61 - 0 ° 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: McArthur River Field, Hemlock Oil & Middle Kenai G Oil Pools, Trading Bay Unit D-01 Sundry Number: 314-294 Dear Mr. Marlowe: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, '1# Daniel . Seamount, Jr. Commissioner DATED this 6 day of May, 2014. Encl. c-c RECEIVED IL STATE OF ALASKA s\t, MAY 0 5 2014 ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS AOGCC 20AAC 25.280 1.Type of Request: Abandon❑ Plug for Redrill❑ Perforate New Pool❑ Repair Well❑ Change Approved Program❑ Suspend❑ Plug Perforations❑ Perforate❑ Pull Tubing 0 r Time Extension 0 Operations Shutdown❑ Re-enter Susp.Well❑ Stimulate❑ Alter Casing❑ Other Replace ESP ED v 2.Operator Name: 4.Current Well Gass: 5. Permit to Drill Number. Hilcorp Alaska,LLC ` Exploratory ❑ Development 9- 167-080 3.Address: 3800 Centerpoint Drive,Suite 1400Stratigraphic ❑ Service ❑ 6.API Number. Anchorage,AK 99503 50-733-20068-00 ' 7. If perforating: 8.Well Name and Number. What Regulation or Conservation Order governs well spacing in this pool? N/A Will planned perforations require a spacing exception? Yes ❑ No❑ Trading Bay Unit/D-01 • 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL0017594• McArthur River Field/Hemlock Oil&Middle Kenai G Oil Pools. 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD(ft): Effective Depth TVD(ft): Plugs(measured): Junk(measured): 12,071 9,798 11,497 9,365 N/A 11,497(fill) Casing Length Size MD TVD Burst Collapse Structural Conductor 716' 20" 716' 716' 1,530 psi 520 psi Surface 2,527' 13-3/8" 2,527' 2,430' 3,090 psi 1,540 psi Intermediate 9,690' 9-5/8" 9,690' 7,945' 5,750 psi 3,090 psi Production Liner 2,494' 7" 12,063' 9,792' 8,160 psi 7,020 psi Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See Schematic / See Schematic 4-1/2" 12.6#/L-80 9,136 Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): N/A N/A / 12.Attachments: Description Summary of Proposal 0• 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch 0• Exploratory ❑ Stratigraphic❑ Development 0• Service ❑ 14.Estimated Date for 15.Well Status after proposed work: Commencing Operations: 5/25/2014 Oil 0' Gas ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: WINJ ❑ GINJ ❑ WAG ❑ Abandoned ❑ Commission Representative: GSTOR ❑ SPLUG ❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Dan Marlowe Email dmarlowe(c�hilcorp.com Printed Name Dan Marlowe Title Operations Engineer Signatur .. gia•Lore..-----Phone (907)283-1329 Date 5/5/2014 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: \ _ 2-c kck Plug Integrity ❑ BOP Test 1EMechanical Integrity Test ❑ Location Clearance ❑ Other: k Z 560 fS.. FTG 1 1 (— Spacing Exception R-,uired? Yes ❑ No (J Subsequent Form Required: I 6—y(b i-{ 0 APPROVED BY 5/P7/ Approved by:Ale COMMISSIONER THE COMMISSION Date: ?"--- eka sick(-rY *4 y ' Submit Form and Form 10-403(R ised 10/2012) Approve Ii lIo *1 is cP f f rjOnths from the date of approval. c s in ca ��--ll ` R��r�� I��' t 3 70 II Well Work Prognosis Well: D-01 Hilcorp Alaska,LLCDate: 05/05/2014 Well Name: D-01 API Number: 50-733-20068-00 Current Status: ESP Producer Leg: Leg#A-2 (northwest) Estimated Start Date: May 25, 2014 Rig: HAK#1 Reg.Approval Req'd? 403 Date Reg.Approval Rec'vd: Regulatory Contact: Juanita Lovett(8332) Permit to Drill Number: 167-080 First Call Engineer: Dan Marlowe (907) 283-1329 (0) (907) 398-9904 (M) Second Call Engineer: Ted Kramer (907)-777-8420(0) (985)-867-0665 (M) AFE Number: Budgeted Cost: Current Bottom Hole Pressure: -3,841 psi @ 9,327'TVD 0.42 psi/foot-August 2009 SBHP Maximum Expected BHP: -3,841 psi @ 9,327'TVD No new perfs Max.Allowable Surface Pressure: 0 psi using 0.46 psi/foot SW Gradient Brief Well Summary D-01 a comingled G and Hemlock producer.The ESP experienced a down-hole failure May 05,2014.We plan to pull and replace the ESP. No perforations will be added.ti Procedure: 1. MIRU HAK#1 Pulling Unit. 2. Attempt to pump through ESP to circulate hydrocarbon off the well to production. If necessary, RU e-line and RIH to+/-9,100'and punch tubing. 3. ND Wellhead, NU BOP and test to 250psi low/2,500psi high.(Note: Notify AOGCC 48 hours in advance of test to allow them to witness test). 4. POOH with tubing string and ESP pump laying down the same. 5. PU,RIH with ESP completion. 6. Land ESP with the bottom of the assembly at+/-9,200'. 7. ND BOP, NU wellhead and test. 8. Turn well over to production. 9. RDMO HAK#1. Attachments: 1. Current Well Schematic 2. Current Wellhead Diagram 3. Proposed Well Schematic 4. BOP Drawing SCHEMATIC Trading Bay Unit • ' H Well: D-01 Hi(cori,Alaska.LL( As Completed: Sept. 20, 2012 RKB=39.10' Rig Floor to DCB CASING DETAIL TBG Spool Size WT Grade Conn ID TopD Btm Hole Cmt t 1 1 Top 20" 94# H-40 8 rd 19.124 Surface 716' 26" 1,600 sxs Surface 13-3/8" 61# J-55 Butt 12.515 Surface 2,527' 17''A" 2,100 sxs Surface 40# N-80 Butt 8.835 Surface 4,860' "24 ii ii.,..„i 4-4 9 5/8„ 43.5# N-80 Butt 8.875 4,860' 6,315' 12/1/2004 2,066 sxs Surface +, 4t. 47# N-80 Butt 8.681 6,315' 8,772' ^y 47# P-110 Butt 8.681 8,772' 9,690' 'ba 20" LINER DETAIL 7" 29# N-80 X-Line 9,569' 12,063' 8-1/2" 820 sxs 9,569' TUBING DETAIL DV ToolIll 13-3/8" 4.5" 12.64 L-80 Hydril 3.958" Surface 9,136' 5,856' , 2 563 SCC i ;i JEWELRY DETAIL rl, 3 ^l No Depth ID Item r,. ..a: 4Le 1 43' 3.908" 4-1/2"Hydril X Butress Box illl2 6,085' Cable Splice from Surface(jt.#206) " 6 M 41 3 9,080' 3.75" XN Profile Nipple w/3.813"Profile(3.75"No-Go) ^' 4 9,136' Top of ESP Assembly 7 5 9,139' Top of ESP Pump-SLB112000N 0gi 6 9,198' Top of Motor 738,18,E-180 Dominator RK-S 7 9,235' Bottom of ESP Assembly FISH IN WELL: 1989:4-1/2"TCP Gun Bull Plug=OD?,.75"long. 6-19-1998:Schlumberger pert gun: 1- fl 3/8"x19"MH-22, 1-11/16"x21"CCL,2-1/8"x19.5"MPD, 2-1/2x42,5"Safe system,2-1/2"x20'HC perf gun(fired),2-1/2"x2"bull plug.=31.8'total length(Top 11,849(+/-I. 2007 ESP WO-Cleaned out wellbore to 11,508' Reperfed G zone Top Liner �'*� 9,569' `;- PERFORATION DETAILS r. 9-5/8" Zone Top(MD) Bottom(MD) Top(TVD) Bottom(TVD) Length Condition t -i G-2 6 SPF,60-deg+PJ Omega KJ' G 3 G-2 10,730' 10,755' 8,764' 8,784' 25' Reperf 2/07 «I 6 SPF,60-deg+PJ Omega GB-41 i G-3 10,795' 10,825' 8,816' 8,840' 30' Reperf 2/07 ' B_2 G-4 10,848' 10,890' 8,859' 8,892' 42' 6 SPF,60-deg+PJ Omega Reperf 2/07 111 B-3 5 SPF,4-1/2"PJ Omega +TOF @ 11,497' !ilkB 4 G-4 10,893' 10,918' 8,894' 8,914' 25' (2/21/07) B-5 B-1 11,250' 11,300' 9,175' 9,214' 50' 6 SPF,60 deg o e, B-2 11,320' 11,410' 9,229' 9,299' 90' Squeezed Fish @ 11,849' '# B-6 B-3 11,435' 11,495' 9,318' 9,363' 60' 6 SPF,60 deg B-4 11,515' 11,670' 9,379' 9,497' 155' 6 SPF,60 deg t} B-5 11,695' 11,850' 9,516' 9,633' 155' 120-deg phasing 7„ B-6 11,865' 11,930' 9,644' 9,693' 65' 120-deg phasing TD=12,071'/PBTD 11,998' ROTATING HOURS ETD=11,849' 28"Drive Pipe - 37 hrs 44.3 deg @ 3,900' 20"Casing - 50.5 hrs 13-3/8"Casing - 275.5 hrs 9-5/8"Casing - 246.5 hrs 7"Casing - 73.5 hrs REVISED:10/17/2012 By:JLL PROPOSED Trading Bay Unit •' EL Well: D-01 Ililcoru Alaska.LLC As Completed: Sept. 20, 2012 RKB=39.10' Rig Floor to DCB CASING DETAIL TBG Spool MD MD Cmt Size WT Grade Conn ID Top Btm Hole Cmt Top 1 20" 94# H-40 8 rd 19.124 Surface 716' 26" 1,600 sxs Surface r* 13-3/8" 61# J-55 Butt 12.515 Surface 2,527' 17'A" 2,100 sxs Surface * "f J 40# N-80 Butt 8.835 Surface 4,860' 14i4 r1 I. 9 5/8„ 43.58 N-80 Butt 8.875 4,860' 6,315' 12/1/2004 2,066 sxs Surface 47# N-80 Butt 8.681 6,315' 8,772' "% 47# P-110 Butt 8.681 8,772' 9,690' ' : * 20 LINER DETAIL i : 7" 29# N-80 X-Line 9,569' 12,063' 8-1/2" 820 sxs 9,569' . ?X13-3/8" TUBING DETAIL DV Tool ; Hydril ., 4.5" 12.6# L-80 3.958" Surface ±9,136' 5,856' 2 , 563 SCC ,J "' aJEWELRY DETAIL 3 No Depth ID Item '"+ 4 1 ±9,200 Bottom of ESP Assembly 145 *N V' 6 r M 7 Ili '14 g 1 i FISH IN WELL: 1989:4-1/2"TCP Gun Bull Plug=OD?,.75"long. 6-19-1998:Schlumberger pert gun: 1- 3/8"x19"MH-22, 1-11/16"x21"CCL,2-1/8"x19.5"MPD, 2-1/2x42,5"Safe system,2-1/2"x20'HC perf gun(fired),2-1/2"x2"bull plug.=31.8'total length(Top 11,849(+/-). 2007 ESP WO-Cleaned out wellbore to 11,508' Reperfed G zone SP4 f Top Liner M* 9,569' * PERFORATION DETAILS • . 9-5/8's Zone Top(MD) Bottom(MD) Top(TVD) Bottom(TVD) Length Condition T 6-2 6 SPF,60-deg+PJ Omega iti' G-3 Iii G-2 10,730' 10,755' 8,764' 8,784' 25' Reperf 2/07 6 SPF,60-deg+PJ Omega 16 G 4 G-3 10,795' 10,825' 8,816' 8,840' 30' Reperf 2/07 B-1 p B_2 G-4 10,848' 10,890' 8,859' 8,892' 42' 6 SPF,60-deg+PJ Omega Reperf 2/07 TOF @ 11,497' ,.1 B-3 G-4 10,893' 10,918' 8,894' 8,914' 25' 5 SPF,4-1/2"PJ Omega m B-4 (2/21/07) la 1'+ B-5 B-1 11,250' 11,300' 9,175' 9,214' 50' 6 SPF,60 deg et B-2 11,320' 11,410' 9,229' 9,299' 90' Squeezed Fish @ 11,849' d . B-6 B-3 11,435' 11,495' 9,318' 9,363' 60' 6 SPF,60 deg B-4 11,515' 11,670' 9,379' 9,497' 155' 6 SPF,60 deg 4,1 B-5 11,695' 11,850' 9,516' 9,633' 155' 120-deg phasing 14 B-6 11,865' 11,930' 9,644' 9,693' 65' 120-deg phasing TD=12,071'/PBTD 11,998' ROTATING HOURS ETD=11,849' 28"Drive Pipe - 37 hrs 44.3 deg @ 3,900' 20"Casing - 50.5 hrs 13-3/8"Casing - 275.5 hrs 9-5/8"Casing - 246.5 hrs 7"Casing - 73.5 hrs Updated by: JLL 05/05/14 Dolly Varden Platform • . H D-01 Current 05/05/2014 ii:km[1 11a-i,::.i_1.1 Dolly Varden BHTA, CIW,4 1/16 5M FE Tubing hanger, CIW D-1 X Cameron internal 20 X 13 3/8 X 9 5/8 X blanking nut DCB ESP, 11 X 4'h IBT 4 1/2 lift and susp,w/4"type -. H BPV profile,5'/4 EN, ml ,,, 11, 2-3/8 continuous AMP control line ports, i.1 1..1 prepped for BIW Valve, swab,WKM-M, lit0 0 Cross, stdd,4 1/16 5M penetrator 4 1/16 5M FE, HWO, `l 0 7i X 3 1/8 5M X 2 1/16 5M T-24 0-0 .10 ISI Valve,wing,WKM-M, I ..44 , -� 2 1/16 5M FE, HWO, � � �,Iq. © Valve,WKM-M, 3 1/8 5M T-24 i FE,w/MA 16 operator 7 put It Valve, lower master, ``1 -,c0q. WKM-M, 4 1/16 5M FE, HWO, T-24 0 0 0 ' 161 1.1 ' "` "' Adapter, CIW-Toadstool, 11 5M Stdd X 4 1/16 5M FE, prepped _i' for 5 '/4 ESP neck, 2-'/2 npt _ continuous control line ports ,_ .- t i Tubing head, CIW-DCB, ''-i 1 ■ in 13 5/8 3M X 11 5M,w/ - i j Qiii 2-2 1/16 5M SSO,X- �' a IF Valve,WKM-M,2 1/16 5M bottom prep, °:.. ° j o a 1 'h VR profile , ``°, ..1,,,,,;:,1,11,...., FE, HWO, DD P �_ . o" n'> w.' Qty 2 iii 1 in Ili Casing spool, CIW-WF, I. ,j,�,_ 21 '/4 2M X 13 5/8 3M, I•� ■'J w/2-2 1/16 5M EFO, 1.�:onio 0Valve, CIW-F, 2 1/16 3M � X-bottom prep I •i ' llit I1 , FE, HWO,AA Tie. I Es: - IIS Casing head, OCT, =1„I 21 '/42MX20SOW, 'a' !/ '1'u �� w/2-2 1/16 2M EFO a 1 i '` Valve, OCT-20, 2 1/16 2M 0,I : �� . qIFE, HWO,AA Dolly Varden Platform •+ 2014 BOP Stack(HAK#1) 01/10/2014 lid',-p,11:e,,k4.1,,4; Dolly Varden Platform 2014 Workovers BOP Drawing(HAK#1) Quail Tool Rental Stack fit til iii iii tit fit lit tit Il 3.42' Shaffer lit lit itlit 111 111 111 111 iii t11 4.54' 1'OD— lit€t!1tl ItI lil €it 111 11E til ttt , 2.00' 1 'Iii til lit til Kill Side Choke side 1.00'to 2.00' 21/16 5M w/HCR and Unibolt line 21/16 5M w/HCR and Unibolt line 111 Miff lit 111 connection connection Drill deck Riser 11 5M FE X 16.00' 11 5M FE lit lit tit tit til 111 Ill III lit til 3.00' Spacer spool 11 5M FE X 11 5M FE tit lit tit lil tit • • Schwartz, Guy L (DOA) From: Dan Marlowe <dmarlowe@hilcorp.com> Sent: Wednesday, May 07, 2014 6:16 AM To: Schwartz,Guy L(DOA) Subject RE: D-01 ESP swap. (PTD 167-080) Last pressure test was 09-13-2012 Set RTTS at 9,050' and tested at 2,200 psi fir 15 minutes From: Schwartz, Gu L DOA mailto: uy.schwartz@alaska. ov Y ( ) � 9 9 ] Sent: May 06, 2014 3:30 PM To: Dan Marlowe Subject: D-01 ESP swap. (PTD 167-080) Dan, I didn't see in the record when the last time the casing was pressure tested. If it has been more than 4 years a casing pressure test to 1500 psi should be done. Guy Schwartz Senior Petroleum Engineer AOGCC 907-301-4533 cell 907-793-1226 office CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Guy Schwartz at (907-793-1226 ) or (Guy.schwartz@alaska.gov). 1 STATE OF ALASKA OCT 1 9 2012 AIL OIL AND GAS CONSERVATION COM SION REPORT OF SUNDRY WELL OPERATIONS AOGCC 1. Operations Abandon ❑ Repair Well ❑ Plug Perforations ❑ Perforate ❑ Other El Installed ESP Performed: Alter Casing ❑ Pull Tubing 131 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 El Exploratory ❑ 167 -080 ".. 3. Address: 3800 Centerpoint Drive, Suite 100 Stratigraphic❑ Service ❑ 6. API Numbers Anchorage, AK 99503 50- 733 - 20068 -00 p CO 7. Property Designation (Lease Number): 8. Well Name and Number: ,. ADL0017594 '' Trading Bay Unit Dolly Varden D -01 9. Logs (List Togs and submit electronic and printed data per 20AAC25.071): 10. Field /Pool(s): N/A McArthur River Field / Hemlock Oil & Middle Kenai G Oil Pools 11. Present Well Condition Summary: Total Depth measured 12,071 feet Plugs measured N/A feet true vertical 9,798 feet Junk measured 11,497 (Fill) feet Effective Depth measured 11,497 feet Packer measured N/A feet true vertical 9,365 feet true vertical N/A feet Casing Length Size MD TVD Burst Collapse Structural 1 Conductor 716' 20" 716' 716' 1,530 psi 520 psi Surface 2,527' 13 -3/8" 2,527' 2,430' 3,090 psi 1,540 psi Intermediate 9,690' 9 -5/8" 9,690' 7,945' 1Y50 psi 3,090 psi Production Liner 2,494' 7" 12,063' 9,792' 8,160 psi 7,020 psi Perforation depth Measured depth See Schematic feet True Vertical depth See Schematic feet SCANNED JAN 2 3 2. Tubing (size, grade, measured and true vertical depth) 4 -1/2" 12.6# L -80 9,136' (MD) 7,527' (TVD) Packers and SSSV (type, measured and true vertical depth) N/A N/A N/A N/A 12. Stimulation or cement squeeze summary: Intervals treated (measured): N/A Treatment descriptions including volumes used and final pressure: N/A 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 0 0 130 130 Subsequent to operation: 232 171 8,854 120 250 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run Exploratory❑ Development El Service ❑ Stratigraphic ❑ Daily Report of Well Operations X 16. Well Status after work: Oil— p Gas ❑ WDSPL❑ GSTOR ❑ WINJ ❑ WAG El GINJ El SUSP❑ SPLUG❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 312 -310 Contact Ted Kramer Email tkramer hilcorp.com Printed Name Ted Kramer Title Sr. Operations Engineer Signature L, Phone 907 - 777 -8420 Date 10/19/2012 R F- 11 :Ali S OCT 2 2 2012 / 1\1 l')rt Form 10 -404 Revised 10/2012 i lr/ Submit Original Only • • • • Trading Bay Unit SCHEMATIC Well: D -01 Hlkm", mask., LH.: As Completed: Sept. 20, 2012 RKB = 39.10' Rig Floor to DCB CASING DETAIL TBG Spool Cmt Size WT Grad Conn ID MD MD Hole Cmt 1 \_ e Top Btm Top 20" 94# H -40 8 rd 19.124 Surface 716' 26" 1,600 sxs Surface 13 -3/8" 61# 1 -55 Butt 12.515 Surface 2,527' 17''/" 2,100 sxs Surface 40# N -80 Butt 8.835 Surface 4,860' I 43.5# N -80 Butt 8.875 4,860' 6,315' 12/1/2004 2,066 sxs Surface i ' 9 -5/8" 47# N -80 Butt 8.681 6,315' 8,772' 20" 47# 110 Butt 8.681 8,772' 9,690' LINER DETAIL 7" 29# N -80 X -Line I 9,569' 12,063' 8 -1/2" 820 sxs 9,569' DV Tool ' ∎'13 - 3/8" TUBING DETAIL 5,856' H 2 4.5" 12.6# L -80 563 s 3.958" Surface 9,136' JEWELRY DETAIL 3 No Depth ID Item 4 1 43' 3.908" 4 -1/2" Hydril X Butress Box 5 iiiF 2 6,085' Cable Splice from Surface (jt. #206) 6 _m 3 9,080' 3.75" XN Profile Nipple w/ 3.813" Profile (3.75" No - Go) MI 4 9,136' Top of ESP Assembly 7 5 9,139' Top of ESP Pump- SLBJ12000N 6 9,198' Top of Motor 738, 18, E -180 Dominator RK -S 7 9,235' Bottom of ESP Assembly FISH IN WELL: 1989: 4 -1/2" TCP Gun Bull Plug = OD ?, .75" long. 6 -19 -1998: Schlumberger perf gun: 1- 3/8 "x19" MH - 22, 1- 11/16 "x21" CCL, 2 -1/8 "x19.5" MPD, 2- 1/2x42,5" Safe system, 2 -1/2 "x20' HC perf gun (fired), 2- 1/2 "x2" bull plug. =31.8' total length (Top 11,849 ( + / -). 2007 ESP WO - Cleaned out wellbore to 11,508' Reperfed G zone Top Liner - 9,569' PERFORATION DETAILS 9 - Zone Top(MD) Bottom(MD) Top(TVD) Bottom(TVD) Length Condition NU G - 6 SPF, 60 -deg+ P1 Omega G -2 10,730' 10,755' 8,764' 8,784' 25' Reperf 2/07 l� G -3 G 6 SPF, 60 -deg + P1 Omega NI G -3 10,795' 10,825' 8,816' 8,840' 30' Reperf 2/07 81 I G -4 10,848' 10,890' 8,859' 8,892' 42' 6 SPF, 60- deg +PJOmega 8 Reperf 2/07 TOF (d@ 11,497' B - G -4 10,893' 10,918' 8,894' 8,914' 25' S SPF, 4 -1/2" PJ Omega i� B - (2/21/07) B -5 B -1 11,250' 11,300' 9,175' 9,214' 50' 6 SPF, 60 deg '' t I B -2 11,320' 11,410' 9,229' 9,299' 90' Squeezed Fish @ 11,849' 45" B -6 B -3 11,435' 11,495' 9,318' 9,363' 60' 6 SPF, 60 deg B -4 11,515' 11,670' 9,379' 9,497' 155' 6 SPF, 60 deg B -5 11,695' 11,850' 9,516' 9,633' 155' 120 -deg phasing 7 „ B -6 11,865' 11,930' 9,644' 9,693' 65' 120 -deg phasing TD = 12,0711 PBTD 11,998' ETD = 11,849' 44.3 deg @ 3,900' REVISED: 10/17/2012 By: AL • • Hilcorp Alaska, LLC Hilcorp Alaska, LLC Weekly Operations Summary Well Name API Number (Well Permit Number Start Date End Date D -01 50- 733 - 20068 -00 167 -080 8/28/2012 9/21/2012 Daily O raga : _ 08/29/12 - Wednesday Install BPV. ND tree - verify hgr thrds - make up 4 -1/2" IBT xo into hgr 13 turns, NU BOPE. R/U accumulator lines, functioin test BOP's. M/U test jt. Fill BOP stack, choke & kill manifold's & lines w /water, shell test. Repair leak on test jt. 08/30/12 - Thursday Test BOPE 250 psi low / 3,000psi high. AOGCC insp Jeff Jones waived witness of test at 0700 8/30/12. RU / FCO safety equip. Well head hand back out LDS, mark landing jt f/ height & orientation. Pull hanger free and monitor well. Continue monitor well, unload ESP pulling equipment. Spot & R/U Pulling equip. Pull hanger t/ window. R/D & L/D hanger assy. Pull ESP assy. start cable & flat pack on spools. POOH. 08/31/12 - Friday POOH w /ESP assy on 4 -1/2" tubing f/ 9,317' t/ 133', L/D jt #6, xo sliding sleeve, & XN profile nipple. R/U crane t/ pull ESP. POOH & L/D ESP pump assy. R/D ESP pulling equip. 09/01/12 - Saturday Finish R/D ESP running equip - clean and organize deck. R/U hawk jaws - lay out 4" HT -38 on deck. M/U 7" scrapper to 1st jt DP. M/U xo for TIW. P/U / M/U 7" scraper w/ hawk jaws - install dies in traveler. RIH w/ 4" DP to jt 42. Install hyd line - pressure test line /manifold. RIH p/u 4" DP t/ 1,962'. P/U 9- 518 " scraper, c.Lo handlingxools t / work string RIH t/ 8,672'... 09/02/12 - Sunday Continue RIH to 9,500' with 7" scrapper - pass thru DV collar at 5,856'. Attempt to rotate scrapper at 9,500' string torqued while moving 4k at stop torques up to 6.2k. R/D circ equip - cont RIH tag at 9,588 ". Try to work thru TOL at 9,569' by rotating, inc down wt up to 4k. POOH. M/U circ equip onto tbg - RIH made tag at 9,588' w /4k drop off 1' to 9,589'. P/U has 10k over pull - inc do wt to 6k - uw increased to 15k -the depth numbers and pipe tall puts us at �19 into the liner. POOH to avoid possible damage to TOL. P P PP tally p g L/D 7 "scrapper, P/ U / RIH w/ 4" DP and 9 -5/8" scrapper. R/D Kelly. POOH, standing back tbg. Continue POOH t/ 9 -5/8" scraper @ 1,971'. Change out handling equip. for BHA & D /P. L/D 9 -5/8" scraper, unload D/P f /boat, Cont POOH w/ 4" D/P & L/D 7" scraper assy. P/U & M/U test jt & test plug, fill stack. Test BOPS W/ 4" test joint 250 psi low / 3,000 psi high. 09/03/12 - Monday Continue with test - 4" rams - repair leaks on connection - tighten head pin - test hydril - top /btm variable rams. All test at 250 psi low / 3,000 psi high. LD test jts test equip. and set wear bushing. Remove slip dies to allow 9 -5/8" scraper to pass thru jack. P/ U / M/U BHA with hawk jaws. RIH with 8 -1/2" bit - 9 -5/8" scraper t/ 1,867'. RIH P/U singles 4" D/P t/ 6,050'. Scale in jts of pipe. Rattling pipe to retrieve rabbit. TIH P/U singles 4" DP t/ 6,237'. 09/04/12 - Tuesday Notify Jim Regg , AOGCC, of upcoming weekly BOPE test scheduled for 9/6/12. Rec'd call 2000 hrs 9/4/12 from Insp. Lou Grimaldi, AOGCC, he plans to witness test. Continue P/U DP and RIH with 8 -1/2" bit, 9 -5/8" scraper from jt # 193 - jt # 214. RIH from jt # 214 to jt # 276. RIH from jt # 276 to jt # 291 @ 9,133'. RIH from jt # 291 to jt # 305 tag TOL at 9,569'. POOH to change from 9 -5/8" scraper to 7" scraper. Continue to L/D DP to deck. P/U / M/U 7" scraper BHA. 09/05/12 - Wednesday Continue RIH with DP to jt # 330 at 9,424'. RIH entering liner at 9,569'. Continue RIH and hard tag at 10,139'. On line with pump at 7 bpm / 700 psi - puw /198k - sow /76k - start washing from 10,139' to 10,150'. Continue washing - hit bridge at 10,164' - work pipe several times at 7 bpm /1200 psi - start rotating w/ 2k do -wash thru 10,181'. POOH. Shutdown pump, POOH to above liner at 9,550'. Start mixing salt pill, keeping hole full. • . Hilcorp Alaska, LLC Hilcoep Alaska, LLC Weekly Operations Summary Well Name API Number (Well Permit Number Start Date End Date D -01 50- 733 - 20068 -00 167 -080 8/28/2012 9/21/2012 17. i 'aerations: 09/06/12 - Thursday Received approval from Jim Regg, AOGCC, to extend BOPE test until out of hole with scraper trip or if not out of hole by EOD 9/7/12 contact Jim Regg. Continue mixing SSP. Prep lines to production and receive approval from TBPF for returns. Pump 70 bbls SSP at 3 bpm followed with 112 bbls FIW injecting into perfs. 100 bbls displaced with hydril and annulus vlv closed WHP starts increasing to 2,000 psi 800 over initial psi. SD pump with 36 bbl in perfs. Monitor WHP - Pump at 1 bpm to squeeze pill into perfs - 8.5 bbls away WHP inc to 1,800 psi 600 over initial psi - with 44.5 bbls pill into perfs and 25.5 left in 7" csg. RD kelly - RIH with 7" scraper. No bridges or bobbles. After ea jt RIH p/u 2 strokes checking wts, at 11,000' hole has been clean so far. 09/07/12 - Friday Received approval from Jim Regg, AOGCC, to extend BOPE test until out of hole with scraper trip or if not out of hole by EOD 9/8/12 contact Jim Regg. RIH tag @ 11,449'. Wash & ream down t/ 11,497'. POOH t/ 7,759'. 09/08/12 - Saturday Clean dies in travelers & heavys. Continue POOH t/ 3,950'. Continue to POOH L/D singles t/ BHA. L/D BHA. Rotary shoe worn down w/ most of leading edge missing. Pull wear bushing. M/U test jt, set test plug, R/U fill up line t/ annulus from trip tank t/ fill & monitor. Test BOPE w/ 4" Jt. 250 psi low / 3,000 psi high, hold each 5 min. Lou Grimaldi, AOGCC witnessed test. 09/09/12 - Sunday Pull test plug, install wear bushing, break down subs & xo's. P/U 7" retrievable brige plug & M /U. RIH w/ retrievable brige plug t/ 10,676'. Set RBP & release. POOH 1 stand. RIH w/ stand, latch onto RBP & release. Let element relax before moving up hole t/ 10,676' & reset. Flood lines, shut in well & pressure up t/ 2,200 psi. Bleed off pressure & open rams. RIH w/ stand, latch onto RBP & release. Let element relax & release before moving up hole. 09/10/12 - Monday Work Plug until released. POOH f/ 10,676' t/ 9,630'. Set RBP in 7" @ 9,630'. Open rams, latch plug & un -set. RIH & set plug @ 9,686'. RIH & latched onto plug, work plug until released. POOH w/ 7" plug, hung up & worked free @ L /T. Continue POOH racking stands t/ 7,529'. Continue POOH laying down singles t/ 635'. POOH t/ BHA. 09/11/12 - Tuesday POOH & I/d 7" RBP. P/U 9 -5/8" RBP. RIH t/ 9,569' lightly tag liner top. P/U t/ 9,549' set RBP. Retrieve plug move t/ 9,519' and reset. Retrieve plug, unset and POOH t/ 6,212'. 09/12/12 - Wednesday Continue POOH t/ 6,500'. Set RBP. Release plug, POOH t/ 5,000', try t/ set RBP w /no success. POOH t/ surface with BHA. RBP was left in hole, last confirmed 6,500'. L/D BHA. M/U RTTS BHA w/ RBP grapple. RIH t/ 5,027', set RTTS & PT t/ 2,200 psi. 09/13/12 - Thursday Release RTTS @ 5,027' after P /T. RIH t/ 9,050', set RTTS. RIH t/ 9,558' tag RBP. Set RBP t/ verify on hook. Unseat RBP, check static fluid loss @ 12 -13 bph. POOH to 3926'. 09/14/12 - Friday POOH w/ 9 -5/8" RTTS & RBP f/ 3,926' t/ BHA. L/D BHA & prep RBP t/ send to beach for rebuild. R/U E -line for USIT log. P/U logging tools & test. RIH t/ 9,750' set up & log 7" past liner lap @ 9,569'. Change out logging tools t/ 9 -5/8 ". RIH t/ liner, TOL @ 9,569'. Log 9 - 5/8" t/ surface. AOGCC notified for 48 HR notice of weekly BOP test. Test witness waived by Jim Regg, AOGCC, @ 09:45 9- 14 -12. • • Hilcorp Alaska, LLC Hilcorp Alaska, LLC, Weekly Operations Summary Well Name API Number IWell Permit Number Start Date End Date D -01 50- 733 - 20068 -00 167 -080 8/28/2012 9/21/2012 Daily 09/15/12 - Saturday Continue 9 -5/8" USIT log. Rig down e-line. Scope out gin pole. P/U 9 -5/8" RBP, RIH w/ RBP t/ 6,298'. Set RBP & verify disconnect. POOH t/ 6,236'. Open rams, breakoff TIW, POOH t/ surface. R/U a -line unit w/ Grey F / Flow Point survey run #1. RIH w/e -line survey tools t/ 6,000'. 09/16/12 - Sunday Continue w/ Flow Point log. R/D e-line & Grey's survey tools. M/U test jt, pull wear ring, set test plug. Pressure test BOP 250 psi low / 3,000 psi high. Jim Regg, AOGCC, waived witness of test @ 9:45 on 9- 14 -12. Due to high winds (58mph) scope in gin pole, wait on wind to pick up a -line tools. 09/17/12 - Monday WOW. Wind slowing down t/ 35 -40 mph. Scope up gin pole, pull test plug and install wear bushing. R/U a -line f/ 2nd Flow Point run. RIH w/ Flow Point tools t/ 6,000' and log. R/D a -line. P/U retrieving grapple BHA f/ RBP. RIH t/ 6,298', tag RBP. Latch & confirm 9 -5/8" RBP. POOH t/ 3,402'. 09/18/12 - Tuesday Continue POOH f/ 3,404' t/ surface. L/D 9 -5/8 RBP. Pull wear bushing. Clear tools from work window, prep f/ ESP. R/U t/ pick up ESP. Test ESP cable, run through sheave, run flat -pak through sheave & r/u test pump. P/U motor install GLM anode, lower through jack. Test flat -pak t/ 5,000 & check valves. P/U M/U seals t/ motor & service. Continue P/U & service ESP pump assy. P/U pot head on jt & M /U. 09/19/12 - Wednesday Continue M/U head flange. P/U #2 jt w/ xn & M /U. RIH t/ 5,396', test flat pak & cable. RIH t/ 5,979', prep f/ splice. C/O cable spool. 09/20/12 - Thursday Finish splice on ESP cable & test. RIH t/ 8,596 ", test cable & flat -pak. RIH t/ 9,177', install xo pup & hanger. Make final splice at tubing hanger in window. Land hanger, run in 1 /d's, back out landing jt's and test. L/D landing jts & 2 stands tubing f/ rig. R/D handling equip. L/D Hydril and double gate and stack on carriers. N/D BOP's. N/U tree. Test tree to t/ 5,000psi. 09/21/12 - Friday Install flow lines t/ tree and test flanges t/ 5,000 psi. R/D Cudd unit. L/D ladder, gin pole and work basket. Rig down and release well to production. Page l of 3 • Schwartz, Guy L (DOA) From: Ted Kramer [tkramer @hilcorp.com] Sent: Friday, September 14, 2012 2:50 PM To: Schwartz, Guy L (DOA) Subject: RE: D -1 Pressure Test Waiver Request pTD 1 G? VO Guy, We checked the logs for the interval between 9100 to 9300 feet like you suggested. There are two small sands in that interval and both are showing a resistivity readings of 10 ohms or less and are therefore considered wet ( Ohm readings of 20 to 30 are desired to be productive). Therefore if they contribute anything at all through the leak, it will be water. To answer your question about the ESP set depth, we always try to set the ESP in a slightly different spot to eliminate the risk of the ESP causing casing damage due to repeatedly laying against the casing wall in the same spot and forming a corrosion cell. We also have traditionally used protectolizers (centralizers) to help hold the ESP off of the casing wall. Having said that, more than likely, where the leak has occurred is most likely in the area of the ESP. We will plan to run some diagnostics now to pinpoint the damage (USIT Log) to be used to formulate the workover plan for the next intervention. We will then run the ESP and set the bottom a little higher than the damaged area. Thanks for your time and attention to this matter. Sincerely, Ted Kramer SCANNED il4AY 0 2 2013 Sr. Operations Engineer Hilcorp Alaska, LLC. 0 907 - 777 -8420 C 985 - 867 -0665 From: Schwartz, Guy L (DOA) [mailto:guy.schwartz @alaska.gov] Sent: Friday, September 14, 2012 1:59 PM To: Ted Kramer Subject: RE: D -1 Pressure Test Waiver Request Ted, Considering the depth of the leak and the fact that the well is fully cemented there is little risk of any well control issue related to this casing leak. I agree with allowing the ESP completion to be run and formulate a plan for the next rig intervention in order to fix the casing leak. 9/14/2012 Page 2 of 3 • Are you considering moving the ESP placement in order to minimize further problems in this area? I would think the leak is somewhere just below the pump intake down the bottom of the motor ( low side corrosion from fill ? ?) Guy Schwartz Senior Petroleum Engineer AOGCC 793 -1226 (office) 444 -3433 (cell) From: Ted Kramer Jmailto:tkramer@hilcorp.coml Sent: Friday, September 14, 2012 12:51 PM To: Schwartz, Guy L (DOA) Subject: D -1 Pressure Test Waiver Request Guy, Hilcorp is requesting a waiver to be able to produce the above well with a deep casing leak until the next ESP replacement. This will allow for the needed time to plan the repair and to order in long lead packers and materials to make a lasting repair. Background The D -1 well produces approximately 10,000 bpd with an ESP as the form of artificial lift. The ESP in this well recently failed when some debris was sucked into the pump intake thereby parting the shaft. Work Summary The CUDD Hydraulic workover unit was mobilized to the Dolly Varden Platform and a workover commenced to repair this pump. The well was cleaned out to 11,497'with a bit and scraper. A 9 -5/8" RTTS packer was then ran in the well and the casing pressure tested above the packer to 2,200 psi. with the following results: Depth (ft) Result 5,000 Good Test — See attached Chart (above DV Tool) 6,500 Good Test — See attached Chart (Below DV tool) 9,521 Test Failed (Liner top at 9,569) 9,511 Test Failed 9,050 Good Test — See attached Chart Offering in Support of Waiver Hilcorp feels that this well is safe to operate with this casing leak and offers the following in support of the Commission granting a waiver to produce the well with the casing leak in this well: 1. The casing leak is located deep in the well. 2. Both the 9 -5/8" casing (OA) and the 13 - 3/8" casing (OOA)had cementing jobs that were circulated to surface. 3. The well has historically been a no flow well and after being shut in since mid July still will not hold a column of fluid. 4. The well will be operated with an ESP and will therefore be operated with minimum pressure on the 9- 5/8" casing. 9/14/2012 Page 3 of 3 • Hilcorp would like to run the ESP and place the well back on production and develop a plan to repair the casing leak at the next ESP replacement. This will allow sufficient time to plan and order long lead packers and materials to make a lasting repair. Hilcorp stands ready to abide by the decision of the commission. However a prompt decision is requested so a work plan can be developed for the weekend. Sincerely, Ted Kramer Sr. Operations Engineer Hilcorp Alaska, LLC. O 907 - 777 -8420 C 985 - 867 -0665 9/14/2012 . , 0 • p.,0( - - ___- , — - , , - ------ - _,, -:-__T-1.--- __-_'------ - ____ • a /4. 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I L n • SCHEMATIC Trading Bay Unit Well: D -01 Hilcorp Alaska, LLC As Completed: Nov. 22, 2011 RKB = 39.10' Rig Floor to DCB Casing Detail TBG Spool MD MD Cmt '-.. - SIZE WT GRADE CONN ID Hole Cmt Top Btm Top 20 94# H -40 8 rd Surface 716' 26" 1,600 sxs Surface 13- 3/8„ 61# 1-55 Butt Surface 2,527' 17 h" 2,100 sxs Surface L 28" 40# N -80 Butt Surface 4,860' 9-5/8" 43.5# N -80 Butt 4,860' 6,315' 12/1/2004 2,066 sxs Surface - 4 20" 47# N -80 Butt 6,315' 8,772' 47# P -110 Butt 8,772' 9,690' Liner Detail - 13 -3/8" 7" I 29# N -80 I X -Line I 9,569' 12,063' I 8 -1/2" 820 sxs I 9,569' DV Tool Tubing Detail 5,856' 4.5" 12.6# L -80 Hydril 3.958" Surface 9,229' 563 SCC Jewelry Detail I NO Depth ID Item 2 1 9,049' 3.813" 4 -1/2" Otis Sliding Sleeve 3 2 9,122' 3.725" XN Nipple, 5.030" OD, 18.92" L 4 3 9,229' 3.833" 4- 1 /2Hydril 563 SCC B x4 -1/2" IBT Pin Butt SCC COME Pup, 12.6#, L -80 Joint IMIlik 5 4 9,227' ND ESP Top Assembly 5 9265' ND Pump Intake 6 6 9241' ND ESP Bottom Assembly Now 7 9318' ND Bull nose FISH IN WELL: 1989: 4-1/2" TCP Gun Bull Plug = OD ?, .75" long. 6 -19 -1998: Schlumberger perf gun: 1- 3/8 "x19" MH -22, 1- 11/16 "x21" CCL, 2 - 1/8 "x19.5" MPD, 2- 1/2x42,5" Safe system, 2 -1/2 "x20' HC perf gun (fired), 2- 1/2 "x2" bull plug. = 31.8' total length (Top 11,849 ( + / -). 2007 ESP WO- Cleaned out wellbore to 11,508' Reperfed G zone Top Liner PERFORATION DETAILS 9,569' . Zone Top(MD) Bottom(MD) Top(TVD) Bottom(TVD) Length Condition --A 9 -5/8" 6 SPF, 60 -deg+ PJ Omega %. G -2 10,730' 10,755' 8,764' 8,784' 25' Reperf 2/07 '0.f ' r Id G G -3 10,795' 10,825' 8,816' 8,840' 30' 6 SPF, 60 deg + PJ Omega G - Reperf 2/07 6 SPF, 60 -deg + PJ Omega G - G -4 10,848' 10,890' 8,859' 8,892' 42' P Re erf 2/07 B-3. 5 SPF, 4 -1/2" PJ Omega r, B - 6-4 10,893' 10,918' 8,894' 8,914' 25' (2/21/07) B _ 3 B-1 11,250' 11,300' 9,175' 9,214' 50' 6 SPF, 60 deg TOF @11,508' ! El B B -2 11,320' 11,410' 9,229' 9,299' 90' Squeezed ; 4 Op it f' ® B 5 B -3 11,435' 11,495' 9,318' 9,363' 60' 6 SPF, 60 deg B -4 11,515' 11,670' 9,379' 9,497' 155' 6 SPF, 60 deg Fish @ 11,849' h ir B - B -5 11,695' 11,850' 9,516' 9,633' 155' 120 -deg phasing B -6 11,865' 11,930' 9,644' 9,693' 65' 120 -deg phasing + '-'E 7 ROTATING HOURS TD = 12,071'/ PBTD 11,998' 28" Drive Pipe - 37 hrs ETD = 11,849' 44.3 deg @ 20" Casing 50.5 hrs 3,900' 13 -3/8" Casing - 275.5 hrs 9 -5/8" Casing - 246.5 hrs 7" Casing - 73.5 hrs REVISED: 8/9/2012 By: TDF P71) /67D6Do Regg, James B (DOA) From: Regg, James B (DOA) !� Sent: Thursday, September 06, 2012 9:41 AM To: Joe McInnis - (C) Cc: Ted Kramer; Harold Soule - (C); Grimaldi, Louis R (DOA); DOA AOGCC Prudhoe Bay Subject: RE: Cudd Rig 136 BOPE Test TBU D -01 PTD 1670800 SCANNED MAY 0 S t 2°13 Cudd 136 Per our phone conversation, you may delay BOPE test until 9/7/12 to provide time to complete fluid loss management. You must test when trip to surface. If you are still working downhole as of 9/7 please contact me about BOPE testing plans. Jim Regg AOGCC 333 W. 7th Ave, Suite 100 Anchorage, AK 99501 907 - 793 -1236 From: Joe McInnis - (C) [mailto:jmcinnis(ahilcorp.com] Sent: Thursday, September 06, 2012 8:59 AM To: Regg, James B (DOA) Cc: Ted Kramer; Harold Soule - (C); Grimaldi, Louis R (DOA); DOA AOGCC Prudhoe Bay Subject: RE: Cudd Rig 136 BOPE Test Jim, I just updated Lou a few moments ago of our well status. Today, Thur 9/6/12 is our scheduled weekly BOPE test. Currently we are conducting a fill clean out at 10000 in the 7" liner, after washing through a 'bridge' the well has started taking fluid at ^'140 bph. We are mixing a sized salt pill to seal the perf's and stop the losses. Typically with this rate of loss it could take two to three pills to seal the perf's off. After we have the fluid loss manageable, with additional pills being pumped as needed, we need to complete our well clean out while we have the fluid Toss manageable. With that said, we estimate being out of the hole around noon on Fri 9/7/12 providing we pump no additional pills. We would like to extend our BOPE test until we are out of the hole on 9/7/12. I will keep you informed of our progress. Thanks, Joe McInnis Dolly Varden 776 -6847 From: Grimaldi, Louis R (DOA) [ mailto :lou.grimaldk63alaska.gov] Sent: Thursday, September 06, 2012 8:11 AM To: Joe McInnis - (C) Cc: Regg, James B (DOA) Subject: Re: Cudd Rig 136 BOPE Test 1 • • Joe, Need an update on status and timing for BOP test please. Lou From: Joe McInnis - (C) [mailto:jmcinnis @hilcorp.com] Sent: Tuesday, September 04, 2012 09:35 AM To: Regg, James B (DOA); DOA AOGCC Prudhoe Bay Cc: Ted Kramer <tkramer @hilcorp.com >; Harold Soule - (C) <hsoule @hilcorp.com> Subject: Cudd Rig 136 BOPE Test Jim, We will be conducting our weekly scheduled BOPE test on CUDD Rig 136, Dolly Varden well D-01 — 48 hrs from today 9/4/12, on Thursday, Sep 6 2012 . Estimate time frame 1200hrs —1800 hrs on 9/6/12. Regards Joe McInnis /Harold Soule DSM — Dolly Varden 907 - 776 -6847 2 • %I if n[LAHKA SEAN PARNELL, GOVERNOR ALASKA OIL AND (irAS 333 W. 7th AVENUE, SUITE 100 CONSERVATION COMMISSION ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276 -7542 Melissa Eisele Sr. Reservoir Engineer 0c6 Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 100 +� Anchorage, AK 99503 Re: McArthur River Field, Hemlock Oil 86 Middle Kenai G Oil Pool, Trading Bay Unit Dolly Varden D -01 Sundry Number: 312 -310 Dear Ms. Eisele: AUG ` 4 IMF. 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 Commission grants for good cause shown, a person affected by it may file with the Commission 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, C4 1 ) / 4 6,05 4 ,........ _ Cathy P. Foerster Chair DATED thi day of August, 2012. Encl. �� -' RECEIVED g. Z STATE OF ALASKA AUG 2012 ALASKA OIL AND GAS CONSERVATION COMMISSION �� APPLICATION FOR SUNDRY APPROVALS 20 MC 25.280 1. Type of Request: Abandon ❑ Plug for RedriN ❑ Perforate New Pod ❑ Repair We ❑ Change Approved Program ❑ Suspend ❑ Plug Perforations ❑ Perforate ❑ Pup Tubing El ' Time Extension ❑ Operations Shutdown ❑ Re - enter Susp. We ❑ Stimulate ❑ Alter Casing ❑ Other:_ Instal ESP El 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number. Hilcorp Alaska, LLC Development p • Exploratory ❑ 167 -080 - 3. Address: Stratigraphic ❑ Service ❑ 6. API Number 3800 Centerpoint Drive, STE 100, Anchorage, AK 99503 50 - 733 - 20068 - - co 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Wel Name and Number property line where ownership or landownership Oranges: Spacing Exception Required? Yes ❑ No G Trading Bay Unit / Dolly Varden 0 9. Property Designation (Lease Number): 10. Field / Pool(s): ADL0017594 ■ McArthur River Field / Hemlock Oil & Middle Kenai G Oil Pools 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 12,071 • 9,798 ' 11,508 9,372 N/A 11,508' Casing Length Size MD TVD Burst Collapse Structural Conductor 716' 20" 716' 715' 1,530 psi 520 psi Surface 2,527' 13 -3/8" 2,527' 2,430' 3,090 psi 1,540 psi Intermediate 9,690' 9 -5/8" 9,690' 7,944' 5,750 psi 3,090 psi Production Liner 2,494' 7" 12,063' 9,792' 8,160 psi 7,020 psi Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): See Schematic See Schematic 4 -1/2" L -80 12.6# 9,229 Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): N/A & N/A N/A & N/A 12. Attachments: Description Summary of Proposal El 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Development El ' Service ❑ 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: 8/20/2012 Oil O ' 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 Ted Kramer (907) 777 -8420 Printed Name Melissa Eisele Title Sr. Reservior Engineer Sign u S Q ,,__ �A ),. Q__ ,Phone (907) 777 -8319 Date 8/8/2012 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 31 2. 3) b Plug Integrity ❑ BOP Test L� Mechanical Integrity Test ❑ Location Clearance ❑ Other: -' 1 ' , t , ` r r Subsequent Form Required: APPROVED BY Approved b y : J 7 , ( COMMISSIONER THE COMMISSION Date: & " — I Z < eV A BDMSAUG 2 3 '01 vi-r- ' t Po rm 10-403 Revised 1/2010 OR1GINF■L.t. �i6' Submit in Du � /l¢ /l z- • • Well Work Plan Well: D-01 n'k`'uri■ :tia.ka. 11C Date: 08/09/2012 Well Name: D -01 API Number: 50- 733 - 2068 -00 Current Status: Oil Production / shut in Leg: Leg A -2, NW Corner Estimated Start Date: August 20, 2012 Rig: Cudd Pressure Control / HWO Reg. Approval Req'd? August 17, 2012 Date Reg. Approval Rec'vd: Regulatory Contact: Tom Fouts Permit to Drill Number: First Call Engineer: Ted Kramer (907) 777 -8420 (0) (985) 867 -0665 (M) Second Call Engineer: Trudi Hallett _ (907) 777 -8323 (0) AFE Number: Current Bottom Hole Pressure: 3841 psi @ 9,327' TVD (calculated SBHP in August 2009 after 4 months of shut -in. Gradient of .416 Maximum Expected BHP: 3700 psi @ 9,327' TVD Max. Anticipated Surface Pressure: 0 psi (This is a No- Flow well) (Using 0.1 psi/ft to surface) Well Summary D - 01 pump failed on July 15 2012. It was producing 9000 + bbls of water and 400 bbls of oil prior to the ESP failure. This will be the 6 ESP installed in this well. Forward Plan: The workover plan would be to simply pull the ESP, make a slickline gauge run to determine max reachable depth, and run a new ESP assembly (800 hp HMI motor) on a 4 -1/2" Hyd503/563 SCC refurbished tubing string and set near the same depth (pump intake at +/- 9241'). Previous pump intakes have been at 9396' (March 2003), 9318' (Feb 2006), 9262' (Feb 2007), 9352' (April 2008) and 9241' (November 2011). Do not plan for installing in GLVs or equipment. Procedure: 1. Pre -Rig planning and platform activities. 2. RU CUDD HWO unit and equipment. 3. ND well head, NU BOP and test (notify AOGCC 48 hours prior to BOP test for opportunity to witness). 4. Pull existing failed ESP completion from well bore. 5. RU slick line and perform gauge and depth runs. 6. Be prepared to make a clean out run with a bit and scraper depending on results of item #5. 7. RIH with RTTS to +/- 9,700'. Pressure test casing to 2,500 psi for 30 minutes. POOH with same. 8. RIH with new ESP completion. 9. ND BOP, NU wellhead and test. 10. RD HWO, release rig. 0 • Well Work Plan Well: D -01 Hilcon) Alaska, LLC Date: 08/09/2012 CURRENT PERFORATION DETAILS Zone Top(MD) Bottom(MD) Top(TVD) Bottom(TVD) Length Condition G -2 10,730' 10,755' 8,764' 8,784' 25' 6 SPF, 60-deg+ PJ Omega Reperf 2/07 G -3 10,795' 10,825' 8,816' 8,840' 30' 6 SPF, 60 deg + PJ Omega Reperf 2/07 G -4 10,848' 10,890' 8,859' 8,892' 42' 6 SPF, 60 deg + PJ Omega Reperf 2/07 G -4 10,893' 10,918' 8,894' 8,914' 25' 5 SPF, 4 -1/2" PJ Omega (2/21/07) B -1 11,250' 11,300' 9,175' 9,214' 50' 6 SPF, 60 deg B -2 11,320' 11,410' 9,229' 9,299' 90' Squeezed B -3 11,435' 11,495' 9,318' 9,363' 60' 6 SPF, 60 deg B -4 11,515' 11,670' 9,379' 9,497' 155' 6 SPF, 60 deg B -5 11,695' 11,850' 9,516' 9,633' 155' 120 -deg phasing B -6 11,865' 11,930' 9,644' 9,693' 65' 120 -deg phasing Attachments: 1. As -built Schematic 2. Proposed Schematic 3. BOP Schematics • 11 0 • SCHEMATIC Trading Bay Unit Well: D -01 'Wiw Alaska, 1,1 A, As Completed: Nov. 22, 2011 RKB = 39.10' Rig Floor to DCB Casing Detail TBG Spool SIZE WT GRADE CONN ID Top MD Hole Cmt T op 20" 94# H -40 8 rd Surface 716' 26" 1,600 sxs Surface 13- 61# 1-55 Butt Surface 2,527' 17 t4" 2,100 sxs Surface 3/8" 28" 40# N -80 Butt Surface 4,860' 43.5# N -80 Butt 4,860' 6,315' 12/1/2004 2,066 sxs Surface 9 -5/8" d 20 „ 47# N -80 Butt 6,315' 8,772' 1 47# P -110 Butt 8,772' 9,690' Liner Detail -4 ' X13 -3/8" 7" 29# N -80 X -Line 9,569' 12,063' 8 -1/2" 820 sxs 9,569' Tubing Detail DV Tool Hydril 5,856' 4.5" 12.6# L-80 563 SCC 3.958" Surface 9,229' Jewelry Detail NO Depth ID Item 1 1 9,049' 3.813" 4 -1/2" Otis Sliding Sleeve 2 3 2 9,122' 3.725" XN Nipple, 5.030" OD, 18.92" L 3 9,229' 3.833" 4- 1 /2Hydril 563 SCC B x4 -1/2" IBT Pin Butt SCC Pup, 12.6 #, L -80 Joint 5 4 9,227' ND ESP Top Assembly 5 9265' ND Pump Intake 6 = 6 9241' ND ESP Bottom Assembly 7 9318' ND Bull nose FISH IN WELL: 1989: 4 -1/2" TCP Gun Bull Plug = OD ?, .75" long. 6 -19 -1998: Schlumberger pert gun: 1- 3/8 "x19" MR 1- 11/16 "x21" CCL, 2 -1/8 "x19.5" MPD, 2- 1/2x42,5" Safe system, 2 -1/2 "x20' HC perf gun (fired), 2- 1/2 "x2" bull plug. = 31.8' total length (Top 11,849 ( + / -). 2007 ESP WO- Cleaned out wellbore to 11,508' Reperfed G zone PERFORATION DETAILS Top Liner 9,569' Zone Top(MD) Bottom(MD) Top(TVD) Bottom(TVD) Length Condition 9 -5/8 G -2 10,730' 10,755' 8,764' 8,784' 25' 6 SPF, 60-deg+ RI Omega Reperf 2/07 G ' 10,795' 10,825' 8,816' 8,840' 30' Re P erf 60 � d 07 G - 60-deg +1 Omega p G -4 10,848' 10,890' 8,859' 8,892' 42' 6 SPF, 60 deg + PJ Omega al G - Reperf 2/07 B -1 5 SPF, 4 -1/2" P1 Omega G -4 10,893' 10,918' 8,894' 8,914' 25' B - (2/21/07) B - B -1 11,250' 11,300' 9,175' 9,214' 50' 6 SPF, 60 deg TOF @ 11,508' '' B 4 B -2 11,320' 11,410' 9,229' 9,299' 90' Squeezed MI ii,i B 5 B -3 11,435' 11,495' 9,318' 9,363' 60' 6 SPF, 60 deg B -4 11,515' 11,670' 9,379' 9,497' 155' 6 SPF, 60 deg Fish @ 11,849' @! 8 - B -5 11,695' 11,850' 9,516' 9,633' 155' 120 -deg phasing B -6 11,865' 11,930' 9,644' 9,693' 65' 120 -deg phasing r zI ' 7" ROTATING HOURS TD = 12,0717 PBTD 11,998' 28" Drive Pipe - 37 hrs ETD = 11,849' 20" Casing - 50.5 hrs 13 -3/8" Casing - 275.5 hrs 44.3 deg @ 3,900' 9 -5/8" Casing - 246.5 hrs 7" Casing - 73.5 hrs REVISED: 8/9/2012 By: TDF • 14 • Proposed Trading Bay Unit Well: D -01 Hilcon) Alaska, LL(: As Completed: Nov. 22, 2011 RKB = 39.10' Rig Floor to DCB Casing Detail TBG Spool SIZE WT GRADE CO ID T ce MD t Hole Cmt Cmt Surf 20" 94# H -40 8 r d a 716' 26" 1,600 sxs Surface 13- 61# J -55 Butt Surface 2,527' 17 % : :" 2,100 sxs Surface 3/8" L 28" 40# N -80 Butt Surface 4,860' 43.5# N -80 Butt 4,860' 6,315' 12/1/2004 2,066 sxs Surface 9 - 5/8" 20 47# N -80 Butt 6,315' 8,772' 47# P -110 Butt 8,772' 9,690' Liner Detail -4' ---13 7" 29# N -80 X -Line 9,569' 12,063' 8 -1/2" 820 sxs 9,569' Tubing Detail DV Tool Hydril 5,856' 4.5" 12.6# L-80 563 SCC 3.958" Surface 9,229' Jewelry Detail NO Depth ID Item I 1 9,049' 3.813" 4 - 1/2" Otis Sliding Sleeve 2 3 2 9,122' 3.725" XN Nipple, 5.030" OD, 18.92" L 4 3 9,229' 3.833" 4- 1 /2Hydril 563 SCC B x4 -1/2" IBT Pin Butt SCC 0 . 00 . Pup, 12.6 #, L -80 Joint 5 4 9,227' ND ESP Top Assembly 5 9265' ND Pump Intake 6 6 9241' ND ESP Bottom Assembly 7 9318' ND Bull nose FISH IN WELL: 1989: 4 -1/2" TCP Gun Bull Plug = OD ?, .75" long. 6 -19 -1998: Schlumberger perf gun: 1- 3/8 "x19" MH -22, 1 - 11/16 "x21" CCL, 2 - 1/8 "x19.5" MPD, 2- 1/2x42,5" Safe system, 2 -1 /2 "x20' HC perf gun (fired), 2- 1/2 "x2" bull plug. = 31.8' total length (Top 11,849 ( + / -). 2007 ESP WO - Cleaned out wellbore to 11,508' Reperfed G zone PERFORATION DETAILS Top Liner 9,569' Zone Top(MD) Bottom(MD) Top(TVD) Bottom(TVD) Length Condition ` - Z 19 G -2 10,730 10,755' 8,764' 8,784' 25 ' 6 SPF, 60 -deg+ PJ Omega Reperf 2/07 G - 6 SPF, 60 -deg + RI Omega G -3 10,795' 10,825' 8,816' 8,840' 30' Reperf 2/07 G - p G -4 10,848' 10,890' 8,859' 8,892' 42' 6 SPF, 60 deg + PJ Omega G - Reperf 2/07 B -1 5 SPF, 4 -1/2" P1 Omega B 2 6-4 10,893' 10,918' 8,894' 8,914' 25' (2/21/07) B - B -1 11,250' 11,300' 9,175' 9,214' 50' 6 SPF, 60 deg TOF @ 11,508' B -2 11,320' 11,410' 9,229' 9,299' 90' Squeezed B - 4 B 5 B -3 11,435' 11,495' 9,318' 9,363' 60' 6 SPF, 60 deg '.4 B -4 11,515' 11,670' 9,379' 9,497' 155' 6 SPF, 60 deg Fish @ 11,849' El" - B -6 B -5 11,695' 11,850' 9,516' 9,633' 155' 120 -deg phasing B -6 11,865' 11,930' 9,644' 9,693' 65' 120 -deg phasing -Lb 7" ROTATING HOURS TD = 12,0717 PBTD 11,998' 28" Drive Pipe - 37 hrs ETD 11,849' 20" Casing - 50.5 hrs 13 -3/8" Casing - 275.5 hrs 44.3 deg @ 3,900' 9 - 5/8" Casing - 246.5 hrs 7" Casing - 73.5 hrs REVISED: 8/9/2012 By: TDF • • Dolly Varden Platform 2012 BOP Stack 05/15/2012 Hde.arp tIaoka. I,II Dolly Varden 2012 ESP Workovers BOP Drawing (Cudd) D -01 4.54' • Hydril • GK 13 5!8 -5000 IC t 4.67' — CI�Q(U — 2 7/8 -5 variables Booster b ,t tts on bolt• . Blind Shear l 1 . l u , i i 2.00' 1:I � , ��:�11: 4 � 4:1 ! i l t '411 0118C ism' 2,83 — 2 7/8 -5 variables ii iiiMit 1. 7' i i i Drill deck Riser 13 5/8 5M FE 14.20' X 13 5/8 5M FE sim ∎1. 1 i ! Spacer spool 2.16' 13 5/8 5M FE X 13 5/8 5M ,i FE �+ t spool i+ Spacer s �iir - P P 2.00' 13 5/8 5M FE X 13 5/8 5M FE 1.41' UOCD .1 I ' Crossover spool 1227 1 i I 13 5/8 5M FE X 11 5M FE Top of wellhead @ 18.60' below deck • • Well Work Plan Well: D -01 Hilcorp Alaska, LLC Date: 08/09/2012 Well Name: D -01 API Number: 50- 733 - 2068 -00 Current Status: Oil Production / shut in Leg: Leg A -2, NW Corner Estimated Start Date: August 20, 2012 Rig: Cudd Pressure Control / HWO Reg. Approval Req'd? August 17, 2012 Date Reg. Approval Rec'vd: Regulatory Contact: Tom Fouts Permit to Drill Number: 167 -080 First Call Engineer: Ted Kramer (907) 777 -8420 (0) (985) 867 -0665 (M) Second Call Engineer: Trudi Hallett (907) 777 -8323 (0) AFE Number: Current Bottom Hole Pressure: 3841 psi @ 9,327' TVD (calculated SBHP in August 2009 , after 4 months of shut -in. Gradient of .416 • Maximum Expected BHP: 3700 psi @ 9,327' TVD Max. Anticipated Surface Pressure: 0 psi (This is a No- Flow well) (Using 0.1 psi /ft to surface) PEFtS ' Well Summary D - 01 pump failed on July 15 2012. It was producing 9000 + bbls of water and 400 bbls of oil prior t the ESP failure. This will be the 6 ESP installed in this well. Forward Plan: The workover plan would be to simply pull the ESP, make a slickline gauge run to determine max reachable depth, and run a new ESP assembly (800 hp HMI motor) on a 4 -1/2" Hyd503/563 SCC refurbished tubing string and set near the same depth (pump intake at +/- 9241'). Previous pump intakes have been at 9396' (March 2003), 9318' (Feb 2006), 9262' (Feb 2007), 9352' (April 2008) and 9241' (November 2011). Do not plan for installing in GLVs or equipment. Procedure: 1. Pre -Rig planning and platform activities. 2. RU CUDD HWO unit and equipment. 3. Pull existing failed ESP completion from well bore. 4. RU slick line and perform gauge and depth runs. 5. RIH with new ESP completion. 6. RD HWO, release rig. TATS OF ALASKA • ALASKA OIL ANWAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon Lf Repair Well U Plug Perforations LJ Stimulate LJ Other U , Replace Failed ESP Performed: Alter Casing ❑ Pull Tubing II Perforate New Pool ❑ Waiver ❑ Time Extension ❑ Change Approved Program ❑ Operat. Shutdown ❑ Perforate El Re -enter Suspended Well ❑ 2. Operator Union Oil Company of Califomia 4. Well Class Before Work: 5. Permit to Drill Number: Name: Development 0 Exploratory ❑ 167 -080 3. Address: PO Box 196247, Anchorage, AK 99519 Stratigraphic ❑ Service ❑ 6. API Number: 50- 733 - 20068 -00 r 0 0 ' 7. Property Designation (Lease Number): 8. Well Name and Number: ADL0017549 [Dolly Varden Platform] Trading Bay Unit D -01 , 9. Field /Pool(s): McArthur River Field/ Hemlock OiI & Middle Kenai G Oil Pools 10. Present Well Condition Summary: Total Depth measured 12,071 • feet Plugs measured N/A feet true vertical 9,798 • feet Junk measured 11,508 (Fill) feet Effective Depth measured 11,508 feet Packer measured N/A feet true vertical 9,372 feet true vertical N/A feet Casing Length Size MD TVD Burst Collapse Structural Conductor 716' 20" 716' 715' 1,530 psi 520 psi Surface 2,527' 13 -3/8" 2,527' 2,430' 3,090 psi 1,540 psi Intermediate 9,690' 9 -5/8" 9,690' 7,944' 5,750 psi 3,090 psi Production Liner 2,494 7" 12,063' 9,792' 8,160 psi 7,020 psi 10,730- 10,755, 10,795- 10,825, 10,848- 10,890, 10,893- 10,918, 11,250- 11,300, 11,320- 11,410, 11,435- 11,495, 11,515 - Perforation depth Measured depth 11,670, 11,695 - 11,850, 11,865- 11,930 8,764 - 8,784, 8,816 - 8,840, 8,858- 8,891, 8,894 - 8,914, 9,174- 9,213, 9,229 - 9,298, 9,317- 9,362, 9,378 - 9,496, 9,515 - True Vertical depth 9,632, 9,643 -9,692 Tubing (size, grade, measured and true vertical depth) 4.5" 12.6 # / L -80 9,228' 7,594' Packers and SSSV (type, measured and true vertical depth) N/A N/A N/A N/A 11. Stimulation or cement squeeze summary: N/A RECEIVED Intervals treated (measured): N/A OF a Treatment descriptions including volumes used and final pressure: N/A AlaCka Oil & Czar Cons. Commission 12. Representative Daily Average Production or Injection Data ,c,- . , ..Y „r:, Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 277 215 9,160 110 130 Subsequent to operation: 423 126 8,384 18 130 13. Attachments: 14. Well Class after work: Copies of Logs and Surveys Run N/A Exploratory❑ Development ` ' Service ❑ Stratigraphic ❑ Daily Report of Well Operations X 15. Well Status after work: Oil - Ell - Gas U WDSPL ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP ❑ SPLUG ❑ 16. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 311 -321 Contact Steve Tyler Phone: 263 -7649 Printed Name Timothy C. Brandenburg Title Drilling Manager 2,---_ ... ) Signature C,” - ` Phone 276 -7600 Date 12/8/2011 Ra[3MS DEC 16 2011 fi� • Z Form 10-404 Revised 10/2010 iod. 0 l (C Submit Original Only / • • - 1r., astab DOLLY VARDEN PLATFORM U N O CAL® WELL #. D -1 76 As- Completed Nov 22, 2011 RKB = 39.10' Rig Floor to DCB TBG Spool i C ASING AND TUBING DETAIL SIZE WT GRADE CONN ID MD Top MD Btm Hole Cmt Cmt Top 20" 94# H -40 8 rd Surface 716' 26" 1600 sxs Surface 13 -3/8" 61# 1 -55 Butt Surface 2,527' 17'''A" 2100 sxs Surface 28" 9 -5/8" 40# N -80 Butt Surface 4,860' 9-5/r 43.5# N-80 Butt 4,860' 6,315' 12 -1/4 2066 sxs Surface } 20" 9-5/8" 47# N -80 Butt 6,315' 8,772' 14 a 9 -5/8" 47# P -110 Butt 8,772' 9,690' Liner 7" 29# N -80 X -Line 9569' 12,063' 8 -1/2" 820 sxs 9569' 13 -3/8" Tubing: DV Tool 4.5" 12.6# 1 -80 Hydril 563 SCC 3.958" Surface 9,228' 5,856' JEWELRY 1 NO Depth ID Item 2 1 9,049' 3.813" 4 -1/2" Otis Sliding Sleeve 3 NMI 2 9,123' 3.725" XN Nipple, 5.08" OD 4 3 9,213' 3.833" 4- 1 /2Hydril 563 SCC B x4 -1/2" IBT Pin Butt SCC Pup t 9,228' ND ESP Top Assembly -Pump Section 5 5 9,265' ND Pump Intake 6 9,280' ND ESP Bottom Assembly -Motor Section 6 7 9,318' ND Bull nose t:a FISH IN WELL: 1989: 4 -1/2" TCP Gun Bull Plug = OD ?, .75" long. 6 -19 -1998: Schlumberger pert gun: 1- w r 3/8 "x19" MH -22, 1 - 11/16 "x21" CCL, 2 -1/8 "x19.5" MPO, 2- 1/2x42,5" Safe system, 2 - 1/2 "x20' HC perf gun (fired), 2- 1/2 "x2" bull Lc plug. = 31.8' total length (Top 11,849 ( + / -). 2007 ESP WO - Cleaned out wellbore to 11,508' Reperfed G zone IQ IQ Top L 9,569' Vr rl F PERFORATION DETAILS „ 9 -5/8" Zone Condition Top Bottom Length Tag Obstruction G _ 2 G -2 6 SPF, 60 deg+ PJ Omega Reperf 2/07 10,730' 10,755' 25' @ 10,160SLM f it: G -3 6 SPF, 60 -deg + PJ Omega Reperf 2/07 10,795' 10,825' 30' 11/18/2011 w!, G - G -4 6 SPF, 60 -deg + PJ Omega Reperf 2/07 10,848' 10,890' 42' G-4 Iva B -1 G -4 5 SPF, 4 -1/2" PJ Omega (2/21/07) 10,893' 10,918' 25' i B -2 B -1 6 SPF, 60 deg 11,250' 11,300' 50' 90' B -2 Squeezed 11,320' 11,410' TOF @ 11,508 11-1 B -3 6 SPF, 60 deg 11,435' 11,495' 60' irk B - B -4 6 SPF, 60 deg 11,515' 11,670' 155' B - 120 -deg Fish @ 11,849' B B -5 phasing 11,695' 11,850' 155' 120 -deg B -6 phasing 11,865' 11,930' 65' ROTATING HOURS TD = 12,071'; PBTD 11,998' 28" Drive Pipe - 37 hrs ETD = 11,849'; 20" Casing - 50.5 hrs 44.3 deg @ 3,900' 13 -3/8" Casing - 275.5 hrs 9 -5/8" Casing - 246.5 hrs 7" Casine - 73.5 hrs REVISED: 12/8/2011 REVISED: TDF Chevron • • 100 Chevron - Alaska Daily Operations Summary Well Name Legal Well Name Lease Surface UWI ChevNo Original RKB (ft) Water Depth (ft) D -01 TRADING BAY UNIT D -01 ADL0017594 5073320068 AR4274 39.10 Job Primary Job Type Job Category Objective Actual Start Date Actual End Date Pump Repair Major Rig 11/6/2011 Work Over (MRWO) Primary Wellbore Affected Wellbore UWI Well Permit Number D -01 507332006800 1670800 DaitY o - . *r • • . 1012412011 00 :00 - 10126/2011 00:00 Operations Summary RU slickline. RIH with 3.79" GR and tag XN nipple at 9,254' SLM. RIH and set 3.75 CSV in XN nipple at 9,254'SLM. Pressure up tubing to 1000psi, OK, verify standing valve in place. RIH w/ and open sliding sleeve at 9,20'SLM, pump down tubing and verified sliding sleeve open. RD slickline. 11/6/2011 00:00 - 11/7/2011 00 :00 Operations Summary MIRU HWO Unit. RU BOP equipment and function test same 250psi low/ 3,000psi high. John Crisp of AOGCC witnessed BOP test. While attempting to install a support beam for Cudd HWO unit, lifting eyes were bent during the process. Notified AOGCC of issue. 11/7/2011 00:00 - 11/8/2011 00:00 Operations Summary RU E -line, RIH w/ 1 -11/16 tubing punch © 9,217' - 9,205' WM - All shots fired, RD E -line. Circulate well w/ 3% KCL. 11/8/2011 00:00 - 1119/2011 00:00 Operations Summary Prepare HWO unit to be rigged down for inspection. Updated Jim Regg AOGCC on status of operations. 11/9/2011 00:00 - 11110/2011 00:00 Operations Summary Continue to RD HWO assembly for inspection. 11/10/2011 00:00 - 11/11/2011 00:00 Operations Summary Perform pull test and mag particle inspection. RU rig and associated equipment. 11111/2011 00:00 - 11112/2011 00:00 Operations Summary Continue to RU HWO assembly and associated equipment. Contacted the AOGCC @ 05:18 Hours 11- 11 -11, Lou Grimaldi, AOGCC inspector, indicated he would witness BOP testing. 11/12/2011 00:00 - 11113/2011 00:00 Operations Summary Continue to RU HWO and associated equipment. Ready to test BOP - Weather hold for helicopter, Lou Grimaldi not able to fly to platform. Lou Grimaldi, AOGCC Inspector waived witness of BOP test. Pressure test BOP equipment with 4 -1/2" test joint to 250 PSI Low/ 3000 PSI High, test annular to 250 PSI Low/ 1500 PSI High. Circulate well w/ 3% KCL. 11/13/2011 00:00 - 11/1412011 00:00 Operations Summary Circulate well over to 3% KCL. Monitor well, pump sized salt bridging pill - Monitor well. Pull hanger - start to pull 4 -12" tubing from well. 11/1412011 00:00 - 11116/2011 00:00 Operations Summary Continue to pull 4 -1/2" ESP completion from well. 11/15/201100:00 - 11/18/2011 00:00 Operations Summary Continue to pull 4 -1/2" ESP completion from well. 11/16/2011 00:00 - 11/17/2011 00:00 Operations Summary Continue to pull 4 -1/2" ESP completion from well. 11/17/2011 00:00 - 11/18/2011 00:00 Operations Summary Continue to POH with ESP completion, LD ESP assembly. 11/1812011 00:00 - 11/19/2011 00:00 Operations Summary RU slickline make guage ring runs. RIH w/2.25" junk bailer to 10,160' MD, POH with slickline, RD slickline, RU to run ESP completion into well bore. 11/19/2011 00:00 - 11/20/2011 00:00 Operations Summary RU to RIH 4 -1/2" ESP completion. 11/20/2011 00:00 -11/21/2011 00:00 Operations Summary Trip in hole with 4 -1/2" 12.6#/ L -80 ESP completion. Land completion at 9,318', pump intake at 9,265'. 11/21/2011 00:00 - 11/22/2011 00:00 Operations Summary ND BOP. Start to RD Equipment and demobilize from platform. 11/22/2011 00;90 - 11/23/2011 00 :00 • Operations Summary Continue to RD Equipment and demobilize from platform. Chevron ' • Chevron - Alaska Daily Operations Summary Well Name Legal Well Name Lease Surface UWI ChevNo Original RKB (ft) Water Depth (ft) D -01 TRADING BAY UNIT D -01 ADL0017594 5073320068 AR4274 39.10 Daily 0'1;0404 11/2312011 00:00 - 11/24/2011 00:00 Operations Summary NU tree, test same to 250psi low /5,000psi high. Continue to RD Equipment and demobilize from platform. • • Page 1 of 2 Maunder, Thomas E (DOA) From: Newell, Jack R. [Swift Technical Services] [JNewell @chevron.com] Sent: Monday, November 28, 2011 11:35 AM To: Maunder, Thomas E (DOA) Subject: RE: BOP Test: Dolly Varden: Sundry 311 -321, 1 (_ 0 Tom , brief follow up on voice message to your office (793 - 1250), The completion went in the well with one run, and had no incidents. We landed on Sunday Nov 20, 2011. The project at the Dolly Varden is complete with the well on production. The gross fluids are being brought up slowly. The Cudd unit has been demobilized to shore and is being cleaned and repaired as needed per CUDD engineers. Jack Jack R. Newell • • - Chevron North America Exploration and Production Midcontinent /Alaska SBU 3800 Centerpoint Drive, Suite 100 Anchorage, Alaska 99503 Tel (907) 263 -7832 Fax (866) 401 0624 Mobile (907) 529 -5450 From: Maunder, Thomas E (DOA) [mailto:tom.maunder @alaska.gov] Sent: Monday, November 28, 2011 8:38 AM To: Newell, Jack R. [Swift Technical Services] Subject: RE: BOP Test: Dolly Varden: Sundry 311 -321, Hi Jack, I know this is a little late in follow up, but how did the operations go on D -01 ?? What is the Cudd Unit doing now? Tom From: Newell, Jack R. [Swift Technical Services] [mailto:JNewell @chevron.com] Sent: Friday, November 18, 2011 8:59 AM To: Regg, James B (DOA); DOA AOGCC Prudhoe Bay Cc: Hammons Jr, Darrell James; Brumley, Rick D. [Nabors]; Bonnett, Nigel (Nigel.Bonnett); Maunder, Thomas E (DOA); Sunderland, Sloan [Swift Technical Services] Subject: BOP Test: Dolly Varden: Sundry 311 -321, Mr. Jim Regg, Per a conversation this morning with Tom Maunder, 11/29/2011 • • Page 2 of 2 On Dolly Varden platform well D -01 Sundry approval 311 -321 we are starting to run in the well with the ESP completion this AM. We expect to be completed with this operation by early Sunday morning. The BOP test is due Saturday November 19, 2011. We request a dispensation for a BOP test in the unlikely event, the completion is not landed until the AM hours of Sunday November 20, 2011. Jack Newell 263 -7832 Jack R Newell • • jnewell @Chevron.com Chevron North America Exploration and Production Midcontinent/Alaska SBU 3800 Centerpoint Drive, Suite 100 Anchorage, Alaska 99503 Tel 1 907 263 -7832 Fax 1 866 401 0624 Mobile 1 907 529 5450 Mail Confidential Footer Privileged /Confidential information may be contained in, or attached to, this message. If you are not the addressee indicated in this message (or responsible for delivery of the message to such person), you may not copy, forward, disclose, deliver, or otherwise use this message or any part of it in any form whatsoever. If you receive the message in error, you should destroy this message after notifying me immediately by replying to the message or contacting me at (907) 263 -7832. 11/29/2011 • • SITAITIE LIEF AILLSIKKA SEAN PARNELL, GOVERNOR ALASKA OIL AND GAS 333 W. 7th AVENUE, SUITE 100 CONSERVATION COMMISSION ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276 -7542 Timothy Brandenburg Drilling Manager � ,o Union Oil Company of Alaska b� 3800 Centerpoint Drive, Suite 100 Anchorage, AK 99503 Re: McArthur River Field, Hemlock Oil and Middle Kenai G Oil Pools, TBU D -01 Sundry Number: 311 -321 Dear Mr. Brandenburg: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for 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, Ag 'I' Daniel T. Seamount, Jr. Chair DATED this2day of October, 2011. Encl. • • Chevron Timothy C Brandenburg Union Oil Company of California %011 Drilling Manager P.O. Box 196427 Anchorage, AK 99519 -6247 %. Tel 907 263 7657 Fax 907 263 7884 Email brandenburgt @chevron.com RECFNED OCT 2 0 ZO11 s' ka Oil & Gas Cans. Conm lSSiolt AI Icheffille October 12, 2011 Commissioner Alaska Oil & Gas Conservation Commission 333 W. 7 th Avenue, Suite 100 Anchorage, Alaska 99501 -3572 O Re: PTD: 167- olly Varden Platform D -01 Application for Sundry Approval: Dear Commissioner, Enclosed for your approval is an Application for Sundry Approval (Form 10 -403) for referenced well. Union Oil Company will work over well D -01 with an alternate surface stack configuration with no shear capability on the 13 -5/8 5M BOP stack. The BOP Stack will have blind rams. If you have any questions pertaining to this information, please contact Jack R Newell (907) 263- 7832. Timothy C. Brand 5-.7—:)'..-7 - --- ' —'-.2 Drilling Manager Enclosure Cc: Well File Union Oil Company of California / A Chevron Company V 1 • STATE OF ALASKA ( t • ECEIVED ALASKA OIL AND GAS CONSERVATION COMMISSION `Ot ' � OCT 2 2011 APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 - kiaska Oil & Gas COMB, .: . 1. Type of Request: Abandon ❑ Plug for Redrill ❑ Perforate New Pool ❑ Repair Well ❑ CtAred Program ❑ Suspend ❑ Plug Perforations ❑ Perforate ❑ Pull Tubing 0 , Time Extension ❑ Operations Shutdown ❑ Re -enter Susp. Well ❑ Stimulate ❑ Alter Casing ❑ Other: Replace Failed ESP El 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Union Oil Company of California Development Ei , Exploratory ❑ 167 -080 • 3. Address: Stratigraphic ❑ Service ❑ 6. API Number: PO Box 196247, Anchorage, AK 99519 50- 733 - 20068 -00. 00 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: Spacing Exception Required? Yes ❑ No 0 Trading Bay Unit D -01 • 9. Property Designation (Lease Number): 10. Field / Pool(s): ADL0017594 (Dolly Varden Platform) McArthur River Field/ Hemlock Oil & Middle Kenai G Oil Pools " 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): 1 Total Depth TVD (ft(`C ); Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 12i ti �� „ i + �� " 11,508 9,372 N/A 11,508' (Fill) Casing Length Size MD TVD Burst Collapse Structural Conductor 716' 20" 716' 715' 1,530 psi 520 psi Surface 2,527' 13 -3/8" 2,527' 2,430' 3,090 psi 1,540 psi Intermediate 9,690' 9 -5/8" 9,690' 7,944' 5,750 psi 3,090 psi Production Liner 2,494' 7" 12,063' 9,792' 8,160 psi 7,020 psi Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 10,730-10,755, 10,795- 8,764-8,784, 8,816 - 8,840, 10,825, 10,848-10,890, 8,858-8,891, 8,894 - 8,914, 10,893-10,918, 11,250- 9,174- 9,213, 9,317- 9,362, 4 -1/2" 12.6 # /L -80 9,225' 11,300, 11,435- 11,495, 9,378-9,496, 9,515 - 9,632, 11,515- 11,670, 11,695- 9,643-9,692 11,850, 11,865- 11,930 Packers and SSSV Type: N/A and N/A Packers and SSSV MD (ft) and TVD (ft): N/A and N/A 12. Attachments: Description Summary of Proposal eg 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch 1511 Exploratory ❑ Development 0 ' Service ❑ 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: 11/15/2011 Oil 0 • Gas ❑ WDSPL ❑ Suspended ❑ 16. Verbal Approval: Date: 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 Jack Newell Phone 263 -7832 Printed Name Timothy C. Brandenburg Title Drilling Manager Signature "Z- - Phone 276 -7600 Date 10/12/2011 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 311 " NI Plug Integrity ❑ BOP Test K Mechanical Integrity Test ❑ Location Clearance ❑ Other: "t)(;) 0 P S \ �� r,J O > A S -k . Wor +■ c►c-wc-.o.VNC. '( V t c s \ 1 CSt■cj t E S> W0 rki..-0..3e` \ \.L`/ Subsequent Form Required: 1,.l(y.,\ /� APPROVED BY �i� \!� Approved by. r COMMISSIONER HE COMMISSION Date: / ®) Z (� I l ' t Form -40 'evised 1/201. ORIGINA Submit in Duplicate ,,,,,,..?„,',,, • DOLLY VA • PLATFORM WELL #: D U 11 O CALe 76 Actual Schematic 5/1/08 RKB = 39.10' Rig Floor to DCB TBG Spool ir 1 : CASING AND TUBING DETAIL SIZE WT GRADE CONN ID MD MD Btm Hole Cmt Cmt Top Top 20" 94# H -40 8 rd Surface 716' 26" 1600 sxs Surface 13 -3/8" 61# J -55 Butt Surface 2,527' 17 W' 2100 sxs Surface ' 28" 9 -5/8" 40# N -80 Butt Surface 4,860' J 9 -5/8" 43.5# N -80 Butt 4,860' 6,315' 12 -1/4 2066 sxs Surface 9 -5/8" 47# N -80 Butt 6,315' 8,772' 20" 9 -5/8" 47# P -110 Butt 8,772' 9,690' Liner 7" 29# N -80 X -Line 9,569' 12,063' 8 -1/2" 820 sxs 9569' Tubing: 13-3/8" 4.5" 12.6# L -80 Butt Mod SCC 3.958" Surface 9,225' 1 DV Tool `, 5,856' -. t ,:t y 4 1, 2 l 4 JEWELRY 3y,a NO Depth ID Item 5 1 9,232' 3.813" 4 -1/2" Otis Sliding Sleeve ',1 2 9,272' 3.75" XN Nipple 6 !i. 3 9,304' 3.958" 4 -1/2 ", 12.6 #, L -80 Butt SCC Pup Joint 4 9,314' Pressure Sub 5 9 „367' 800 HP (725 Series) ESP Assy ? 6 9,403' Bull nose FISH IN WELL: 1989: 4 -1/2" TCP Gun Bull Plug = OD ?, .75" long. 6-19-1998: Schlumberger perf gun: 1 -3/8 "x19" MH -22, 1- 11/16 "x21" CCL, 2 -1/8 "x19.5" MPD, 2- 1/2x42,5" Safe system, 2 -1/2 "x20' HC perf gun (fired), 2- 1/2 "x2" TO Liner bull plug. = 31.8' total length (Top 11,849 ( +b). 2007 ESP WO - Cleaned out welibore to 11,508' Reperfed G zone P 9,569' $ e h 9 -5/8" PERFORATION DETAILS t, i * ' Zone Condition Top Bottom Length G 2 G -2 6 SPF, 60 -deg+ PJ Omega Reperf 2/07 10,730' 10,755' 25' lla G -3 6 SPF, 60 -deg + PJ Omega Reperf 2/07 10,795' 10,825' 30' i «- G - 3 G -4 6 SPF, 60 -deg + PJ Omega Reperf 2/07 10,848' 10,890' 42' *0 G -4 G-4 5 SPF, 4 -1/2" PJ Omega (2/21/07) 10,893' 10,918' 25' 1 t B-1 B -1 6 SPF, 60 deg 11,250' 11,300' 50' B -2 B -2 Squeezed 11,320' 11,410' 90' - R -3 B -3 6 SPF, 60 deg 11,435' 11,495' 60' TOF @ 11,508 1 tit B-4 6 SPF, 60 deg 11,515' 11,670' 155' B -4 LM B - 120 -deg ' O z., B -5 phasing 11,695' 11,850' 155' Fish @ 11,849 B 120 - deg B - 6 phasing 11,865' 11,930' 65' 7" ROTATING HOURS 28" Drive Pipe - 37 hrs 20" Casing - 50.5 hrs TD = 12,063'; PBTD 11,998' 13 - 3/8" Casing - 275.5 hrs ETD = 11,849'; 9 - 5/8" Casing - 246.5 hrs 44.3 deg @ 3,900' 7" Casing 73.5 hrs O:\ NAU \MCBU\Alaska\Depts \CI_OiI_Ops\ Fields \TBU\Dolly\ Wells \Producers\D- 01 \Schematics\D -01 Schematic 5- 1- 08.doc REVISED: 5/1/08 REVISED: BCA/CRW r • DOLLY VARDEN PLATFORM UNOCAL() WELL #: D -1 Proposed Schematic Nov 2011 RKB = 39.10' Rig Floor to DCB TBG Spool C ASING AND TUBING DETAIL SIZE WT GRADE CO ID MD MD Hole Cmt Cmt Top Top Btm L U 20" 94# H -40 8 rd Surface 716' 26" 1600 Surface 2 sxs 28" 13- 61# J -55 Butt Surface 2,527' 1714" 2100 Surface 3/8" sxs 20" 9 - 5/8" 40# N -80 Butt Surface 4,860' 9 -5/8" 43.5# N -80 Butt 4,860' 6,315' 12- 2066 Surface 9 -5/8" 47# N -80 Butt 6,315' 8,772' 1/4 sxs 13 - 3/8" 9 - 5/8" 47# P -110 Butt 8,772' 9,690' DV Tool Liner 5,856' 7" 29# N -80 X -Line 9,569' 12,063' 8- 820 sxs 9569' 1/2" Tubing: I 4.5" 12.6# L -80 Hydril 563 SCC 3.958" Surface ±9023' 2 3 . JEWELRY 4 » NO Depth ID Item 1 ±9,092' 3.813" 4 -1/2" Otis Sliding Sleeve 5 = 2 ±9,152' 3.725" XN Nipple, 5.030" OD, 18.92" L 3 ±9,239' 3.833" 4- 1 /2Hydril 563 SCC B x4 -1/2" IBT Pin Butt SCC Pup, 12.6#,L- .... 6 80 Joint 4 ±9,240' ND ESP Top Assembly 5 ±9,290' ND Pump Intake 6 ND ESP Bottom Assembly 7 ±9,338' ND Bull nose FISH IN WELL: 1989: 4 -1/2" TCP Gun Bull Plug = OD ?, .75" long. 6 -19 -1998: Schlumberger perf gun: 1- 3/8 "x19" mu 1- 11/16 "x21" CCL, 2 -1/8 "x19.5" MPO, 2- 1/2x42,5" Safe system, 2 -1 /2 "x20' HC perf gun (fired), 2- 1/2 "x2" bull plug. = 31.8' total length (Top 11,849 ( + / -). 2007 ESP WO- Cleaned out wellbore to 11,508' Reperfed G zone Top Liner 9,569' 9 -5/8" PERFORATION DETAILS r Zone Condition Top Bottom Length 2 G -2 6 SPF, 60 -deg+ PJ Omega Reperf 2/07 10,730' 10,755' 25' it G -3 6 SPF, 60 -deg + PJ Omega Reperf 2/07 10,795' 10,825' 30' G -3 G -4 6 SPF, 60 -deg + PJ Omega Reperf 2/07 10,848' 10,890' 42' - G -4 G -4 5 SPF, 4 -1/2" PJ Omega (2/21/07) 10,893' 10,918' 25' B - B -1 6 SPF, 60 deg 11,250' 11,300' 50' v B - B -2 Squeezed 11,320' 11,410' 90' TOF ri 11,51 R_i B -3 6 SPF, 60 deg 11,435' 11,495' 60' TOF @ 11,508 B -4 B -4 6 SPF, 60 deg 11,515' 11,670' 155' 13-5 120 -de A. �°' B -5 phasing 11,695' 11,850' 155' Fish @ 11,849' t ' B 120 -deg B -6 phasing 11,865' 11,930' 65' r * iS:4 11 ,7" I ROTATING HOURS 1 TD = 12,063'; PBTD 11,998' 28" Drive Pipe - 37 hrs ETD = 11,849'; 20" Casing - 50.5 hrs 44.3 deg @ 3,900' 13 -3/8" Casing - 275.5 hrs 9 -5/8" Casing - 246.5 hrs 7" Casine - 73.5 hrs REVISED: 8- 24/2011 REVISED: JRN Chevron • T>•ng Bay Unit 1110 D-01 %. BOP Configuration Revision #0: 10/11/2011 Dolly Varden Platform D -01 Nordic BOPE MI 4.54' • Hydril Q GK 135/ &5.' Nordic owned 111 lil I 1 Shaffer SL 5/8 5M _ Nordic owned 13 1.44' 0 2 1/16 5M choke and kill lines unbolt ends , . - 111 111 111111 111 a _ Ili `I ��III�II .1;., iim I 0w . I .(1iII ( •II1: 1.74' 111 111 111 111 111 r Ali haffer SL • - Nordic owned __ 1.44' 111 111411 1 111 .5 Drill deck UOCD 3437 Riser 11.00' 13 5/8 5M X 13 5/8 5M 111 111 111 111 111 1111111111111 , 111 III 111 111 111 Crossover spool 1.41' UOCD. 13 5/8 5M Flanged end X 1 1227 11 5M Flanged end 111111 lil 111111 ".€ ili i un '''' i.' , r ) , ii , .. i1t , Il�. ,. `� ` , ,„, a 1_,.._: D -01 BOP stackup 2011.docx REVISED BY JRN 10/11/2011 Chevron • Ting Bay Unit /11100 D -01 ESP Replacement WO Revision #0: 10/12/2011 OBJECTIVE: Recover current ESP completion — Perform gauge ring run, tag top of fill — Run new ESP completion on 4- / 1/2" Tubing— Return well to production as producing oil well. Current BHP: 3,782psi @ 9,237' TVD 8.2 PPG EMW Max BHP: 3,782psi @ 9,237' TVD 8.2 PPG EMW (Based on previous actual Phoenix Reading) MASP: 909 PSI surface pressure based on current 3 month shut in period. 94% WC and GOR 354 PROCEDURE SUMMARY: • Mobilize Cudd Energy Services HWO. • ND Tree - NU BOPE - Test BOPE Equipment to 250psi low /3,000psi high. Test Annular to 250 PSI Low / 1,500 PSI High. • RU Slickline, RIH and shift open sliding sleeve at 9,232'. RD Slickline • Circulate well bore with 3% KCL/ filtered inlet water — Pump designed salt pill as required. • POOH with 4 -1/2" ESP Completion. • RU Slickline, Perform gauge ring run to tag top of fill @ +/- 11,508' POH, RD Slickline. • PU new ESP and place pump intake ±9,290' MD — land hanger. • ND BOP — NU Tree — Pressure Test to 250psi low/ 5,000psi high. • Turn over to operations. D -01 WO _Objective_and_Procedure_Summary 10- 12- 2011.docx STATE OF ALASKA MAY 0 7 2008 ALA~OIL AND GAS CONSERVATION COM~ON REPORT OF SUNDRY WELL OPERATION~aska Oil & Gas Cons. Commission h ra e 1. Operations Abandon Repair Well ~ ~ Plug Perforations Stimulate Other ~ Replace Failed Performed: Alter Casing ^ Pull Tubing Q Perforate New Pool ^ Waiver ^ Time Extension ^ ESP ` Change Approved Program ^ Operat. Shutdown ^ Perforate ^ Re-enter Suspended Well ^ 2. Operator Union Oil Company of Ca{ifornia 4. Current Well Class: 5. Permit to Drill Number: Name: Development Q Exploratory^ 167-080 3. Address: PO Box 196247, Anchorage, AK 99519 Stratigraphic^ Service ^ 6. API Number: 50-733-20068-00 ' 7. KB Elevation (ft): 9. Well Name and Number: 106' RT above MSL D-01 ' 8. Property Designation: 10. Field/Pool(s): Dolly Varden Platform/ADL 017594 Hemlock Oil/Middle Kenai G Oil 11. Present Well Condition Summary: Total Depth measured 12,071' feet Plugs (measured) n!a true vertical 9,798' ~ feet Junk (measured) 11,849' Effective Depth measured 11,849' feet true vertical 9,743' feet Casing Length Size MD TVD Burst Collapse Structural Conductor 716' 20" 716' 715' 1530 psi 520 psi Surface 2,527' 13-3/8" 2,527' 2,430' 3,090 psi 1,540 psi Intermediate 9,690' 9-5/8" 9,690' 7,944' 5,750 psi 3,090 psi Production Liner 2,494' 7" 12,063' 9,792' 8,16 0 psi 7,020 psi Perforation depth: Measured depth: 10,730 to 11,930' ~~yy x c~~0~ MAY ~ Z~Ou True Vertical depth: 8,764 to 9,692' Tubing: (size, grade, and measured depth) 4-1/2", 12.6#, N-80 @ 9,271' Packers and SSSV (type and measured depth) n/a 12. Stimulation or cement squeeze summary: Intervals treated (measured): n/a Treatment descriptions including volumes used and final pressure: ~r.)5~~ ~~:- ~"`~~ ~~ ?~0~ 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 0 0 Subsequent to operation: 242 0 9,457 160 psi 120 psi 14. Attachments: 15. Well Class after proposed work: Copies of Logs and Surveys Run Exploratory^ Development Q ~ Service ^ Daily Report of Well Operations X 16. Well Status after proposed work: OilO Gas ^ WAG ^ GINJ ^ WINJ ^ WDSPL ^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 308-114 Contact Chantal Walsh 263-7627 Printed Name Timothy C. Brandenburg Title Drilling Manager Signature .i C ~%~ Phone 907-276-7600 Date 5/6/2008 Form 10-404 evised 04/2004 ~ ~ , ~ N ~ I AFE 164805 ~`,~~~ Submit Original Only Chevron., ~ Chevron -Alaska Daily Operations Summary Well Name Field Name APIIUWt Lease/Serial Orig FCt3 Elev (fttC6) Water Depth (ft) D-01 MCARTHUR 507332006800 ADL0017594 39.1 Jobs AFE No. OC Eng R8024 Daily Operations 4/19/2008 00:00 - 4/20/2008 00:00 Operations Summary RU slickline. RIH w/3.8" Gauge Ring set down at 9179' RKB at XN nipple (had to work through sliding sleeve). PIH w/ PXN plug assy. Had issues with paraffin. After 3rd run set tool at XN nipple. POOH. RIH with equalizing prong and set into plud and sheared off prong. POOH. Secured well. 4/20/2008 00:00 - 4/21/2008 00:00 Operations Summary SIMOPS. Filled tubing with water. Pressured tbg to 500 psi for 10 min. RIH with shifting tool. Opened sliding sleeve. Immediately lost pressure in tubing. POOH. RD slickline. Mobing crews and equipment onto platform. 4/21/2008 00:00 - 4/22/2008 00:00 Operations Summary Mobe equipment. 4/22/2008 00:00 -4/23/2008 00:00 Operations Summary Mobe, rigging up and notify AOGCC of BOP test. 4/23/2008 00:00 -4/24/2008 00:00 Operations Summary Mix kill fluid, pump kill fluid and start nipple down of wellhead. 4/24/2008 00:00 - 4/25/2008 00:00 Operations Summary ND wellhead. NU BOP. Test same (250 psi low/3000 psi high). 4/25/2008 00:00 - 4/26/2008 00:00 Operations Summary PE test. Perform mask up drills. Pump 3% KCL water through tubing, taking returns to tank. Total pumped = 280 bbls. Static losses = 80bph. BO LDS and pu anger to floor. Check splice under hanger -lead still dead. Re land hanger. Mix and pump sized salt pill. Spo s size a pl to sliding sleeve. Shut annulur and bullhead to formation. 4/26/2008 00:00 - 4/27/2008 00:00 Operations Summary PJSM. Remove TIW valve and pump in sub, drift with 3.85". MU TIW and Pump in Sub. RU slickline, latch and pull prong free. RU slickline. Fill wellbore. Static losses = 1.5bph. BO LDS. pull hanger to floor. PUMU ESP cable to spool. Pull tubing out of hole. Cut splices out to analyse. Losses from 1.0 - 1.4 bph. 4/27/2008 00:00 - 4/28/2008 00:00 Operations Summary TOOH w/ESP.. ESP cable above flat motor lead splice corroded. LD sliding sleeve, XN nipple. Indications cable shorted out at Motor Lead Splice. LD ESP Assembly. Recovered all clamps, an s an pro e o Izers. PUMU new ESP BHA. Test motor lead connection and Phoenix gauge communication. Close sliding sleeve. Pull body from XN nipple. RIH w/equipment. 4/28/2008 00:00 - 4/29/2008 00:00 Operations Summary MU ESP pump assembly and test same. RIH with 4-1/2" IBT tubing, running cannon clamps on every other collar. Test conductivity every 10 stands. RIH and land anode at 9405', P/U 160K Slack Off 110K. Run lock down screws. 4/29/2008 00:00 - 4/30/2008 00:00 Operations Summary ND BOP NU Tree. Pressure test tree 250 low and 5000 high. Demob rig 4/30/2008 00:00 - 5/1/2008 00:00 Operations Summary Demob Rig 5/1/2008 00:00 - 5/2/2008 00:00 Operations Summary Demob Rig 5/2/2008 00:00 - 5/3/2008 00:00 Operations Summary Demob Rig 5/3/2008 00:00 - 5/4/2008 00:00 Operations Summary Demob rig 5/4/2008 00:00 - 5/5/2008 00:00 Operations Summary Demob rig Chevron Chevron -Alaska Daily Operations Summary Well Name D-01 Field Name MCARTHUR API/UWI 507332006800 Lease/Serial ADL0017594 Orig KB Elev (ftK6) 39.1 Water Depth (ft) Daily Operations 5/5/2008 00:00 - 5/6/2008 00:00 Operations Summary Demob rig '~ DOLLY V DEN PLATFORM U ~ O ~~~© WELL #: D-1 7(i Actual Schematic 5/1/08 RKB = 39.10' Rig Floor to DCB TBG Spool D Tc 9: TOF Fish TD =12,063'; PBTD 11,998' ETD = 11,849'; 44.3 deg @ 3900' D-1 Schematic C`ACiNG ANn TiTRiNG nF.TAii. SIZE WT GRADE CONN ID MD To MD Btm Hole Cmt Cmt Top 20" 94# H-40 8 rd Surface 716' 26" 1600 sxs Surface 13-3/8" 61# J-55 Butt Surface 2527' 17 %:" 2100 sxs Surface 9-5/8" 40# N-80 Butt Surface 4860' 9-5/8" 43.5# N-80 Butt 4860' 6315' 12-1/4 2066 sxs Surface 9-5/8" 47# N-80 Butt 6315' 8772' 9-5/8" 47# P-110 Butt 8772' 9690' Liner 7" 29# N-80 X-Line 9569' 12,063' 8-1/2" 820 sxs 9569' Tubin 4.5" 12.6# L-80 Butt Mod SCC 3.958" Surface 9225' I' NO Depth ID JEWELRY Item 1 9232' 3.813" 4-112" Otis Sliding Sleeve 2 9272' 3.75" XN Nipple 3 9304' 3.958" 4-1/2", 12.6#, L-80 Butt SCC Pup Joint 4 9314' Pressure Sub 5 9367' 800 HP (725 Series) ESP Assy 6 9403' Bull nose FISH IN WELL: 1989: 4-1/2" TCP Gun Bull Plug = OD ?, .75" long. 6-19-1998: Schlumberger perf gun: I-3/8"x19" MH-22, 1-11/16"x21" CCL, 2-1/8"x19.5" MPD, 2-1/2x42,5" Safe system, 2-1.2°x20' HC perf gun (fired), 2-1/2"x2" bull plug. = 31.8' total length (Top 11,849 (+E). 2007 ESP WO -Cleaned out wellbore to 11,508' Reperfed G zone PERFORATION DETAILS Zone Condition To Bottom Len th G-2 6 SPF, 60-deg+ PJ Ome a Re erf 2/07 10,730.00 10,755.00 25.00 G-3 6 SPF, 60-deg + PJ Ome a Re erf 2/07 10,795.00 10,825.00 30' G-4 6 SPF, 60-deg + PJ Ome a Re erf 2/07 10,848.00 10,890.00 42' G-4 5 SPF, 4-1/2" PJ Ome a 2/21/07 10,893' 10,918' 25' B-1 6 SPF, 60 de 11,250.00 11,300.00 50.00 B-2 S ueezed 11,320.00 11,410.00 90.00 B-3 6 SPF, 60 de 11,435.00 11,495.00 60.00 B-4 6 SPF, 60 de 11,515.00 11,670.00 155.00 B-5 120-de hasin 11,695.00 11,850.00 155.00 B-6 120-de hasin 11,865.00 11,930.00 65.00 ROTATING HOURS 28" Drive Pipe - 37 hrs 20" Casing - 50.5 hrs 13-3/8" Casing - 275.5 hrs 9-5/8" Casing - 246.5 hrs 7" Canine - 73.5 hrs REVISED: 5/1/08 REVISED: BCA/CRW ALASSA OIL A1~TD GAS COI~TSERQATIOI~T COMi~IISSIOrT Timothy Brandenburg Drilling Manager UNOCAL PO Box 196247 Anchorage, AK 99519 Re: McArthur River Field, Hemlock Oil Pool, D-O1 Sundry Number: 308-114 • SARAH PAL/N, GOVERNOR 333 W. 7th AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 a ~~_o~ Dear Mr. Brandenburg: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, Daniel T. Seamount, Jr. .1~ Chair DATED this ~ day of April, 2008 Encl. ~~ ~ ~~ A ~ STATE OF ALASKA QTR g ~i~ ALA OIL AND GAS CONSERVATION COM ION APPLICATION .FOR SUNDRY APPR ~lll~l~-~fl & Gas C s, minissc~t 20 AAC 25.280 1. Type of Request: Abandon^ Suspend ^ Operational shutdown ^ Perforate ^ Waiver OtherO Alter casing^ Repair well ~ ~ Plug Perforations ^ Stimulate ^ Time Extension ^ ESP Change out ~ Change approved program^ Pull Tubing^ ~~~ Perforate New Pool ^ Re-enter Suspended Well ^ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Chevron/ Union Oil Company of California Development ^ Exploratory ^ 167-080 ' 3. Address: Stratigraphic ^ Service ^ 6. API Number: PO Box 196247, Anchorage, Alaska 99519 50-733-20068-00 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. WeII Name and Number: property line where ownership or landownership changes: Spacing Exception Required? Yes ^ No ~ D-01 9. Property Designation: 10. KB Elevation (ft): 11. Field/Pool(s): Doll Varden Platform/ADL017594 ' 39.1'RigfloortoDCBTbgSp HEMLOCK OIL; MIDDLE KENAI G OIL ' 12. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 12,071' 9798' ~ 11,849' 9743' n/a 11,849' Casing Length Size MD TVD Burst Collapse Structural Conductor 716' 20" 716' 715' 1530 psi 520 psi Surface 2527' 13-3/8" 2527' 2430' 3090 psi 1540 psi Intermediate 9690' 9-518" 9690' 7944' 5750 psi 3090 psi Production Liner 2494' 7" 12,063' 9792' 8160 psi 7020 psi Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 10,730' - 11,930' 8,764' to 9,692' 4-1l2" L-80 9239' Packers and SSSV Type: Packer-less Completion (no flow) Packers and SSSV MD (ft): Packer-less Completion 13. Attachments: Description Summary of Proposal Q 14. We11 Class after proposed work: Detailed Operations Program ^ BOP Sketch ~ Exploratory ^ Development Q Service ^ 15. Estimated Date for 4/21/2008 16. Well Status after proposed work: Commencing Operations: Oil 0 Gas ^ Plugged ^ Abandoned ^ 17. Verbal Approval: Date: WAG ^ GINJ ^ WINJ ^ WDSPL ^ Commission Representative: 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Steve Tyler - 263-7649 Printed Name Timothy C. Brandenburg Title Drilling Manager Signature ~_ -~ Pho 907-276-7657 Date 3/20/2008 e`-` COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: ~~~ ~~ Plug Integrity ^ BOP Test ~. Mechanical Integrity Test ^ Location Clearance ^ Other: ~dd ~ per' ~ ,~~'~~~aJ ~ ~~ ~S~ vy©~-\~ ~ r. ~.~~...v~c~.~~ ~"'' l ~~c~.~' C.~z~coh ~S~ ~No~~vE ~~ ~o ~~~~ Subsequent Form Required: ~~y/ gg ,s;;,+ ~} APPROVED BY Approved by: OMMISSIONER THE COMMISSION Date: ~ ..~~~~ .v-,w ~.cv~ocu vwavv~ ;. . _ ~ ui~'• ui vupm Chevron ~ • ~, Dolly Varden Platform Well D-O1 '08 ESP Workover OBJECTIVE: Replace the failed ESP assembly currently in Well D-O1 PROCEDURE SUMMARY: 1. RIU Slickline. Open Sliding Sleeve above ESP. 2. Circulate oil out of annulus and load well w/ 3% KCL. 3. Activate Dolly Varden Rig. 4. Spot sized salt pill (if necessary} to manage losses and keep hole full while POH. 5. Set BPV and N/D tree on Well D-O1. N/U BOPE. Test 13-5/8" BOPE. 6. Verify well dead. 7. POH w( tubing, cable & failed ESP. 8. R/U to run the ESP completion. 9. RIH w/ replacement ESP assembly on tubing. 10. Install BPV. N/D BOPE. N/U & test tree. AOGCC D-1 ESP WO Procedure Summary.doc 1 of 1 January 3, 2008 • • 3 1/8" SM DSA Rentals possibly X 2 1H6" 5M DSA owned by UOCD 3 5/8" SM by 2 1/16" 6M Kill Lines are 3 1/8" SM Integral Flanges Dolly Varden Stack up D -1 .~,. DOLLY VARDEN PLATFORM U N O CA L ~6 WELL #: D-I Actual Schematic 3/28/07 RKB = 39.10' Rig Floor to DCB TBG Spool D` TOE 95t TOF Fish @ TD =12,063'; PBTD 11,998' ETD = 11,849'; 44.3 deg @ 3900' CASING AND TTJRTN(: nFTATT, SIZE WT GRADE CONK ID MD To MD Btm Hole Cmt Cmt Top 20" 94# H-40 8 rd Surface 716' 26" 1600 sxs Surface 13-3/8" 9-5/8" 61# 40# J-55 N-80 Butt Butt Surface Surface 2527' 4860' 17'/," 2100 sxs Surface 9-5/8" 43.5# N-80 Butt 4860' 6315' 12-1/4 2066 sxs Surface 9-5/8" 47# N-80 Butt 6315' 8772' 9-5/8" 47# P-110 Butt 8772' 9690' Liner 7" 29# N-80 X-Line 9569' 12,063' 8-1/2" 820 sxs 9569' 'Cabin 4.5" 12.6# L-80 Butt Mod SCC 3.958" Surface 9225' NO Depth ID JEWELRY Item 1 2488' 3.833" 4-1/2" GLM #7, RK Latch and R-2 Valve 2 4220' 3.833" 4-1/2" GLM #6, RK Latch and R-2 Valve 3 5649' 3.833" 4-1/2" GLM #5, RK Latch and R-2 Valve 4 6412' 3.833" 4-1/2" GLM #4, RK Latch and R-2 Valve 5 6988' 3.833" 4-1/2" GLM #3, RK Latch and R-2 Valve 6 7535' 3.833" 4-1/2" GLM #2, RK Latch and R-2 Valve 7 8110' 3.833" 4-1/2" GLM #1, RK Latch and R-2 Valve 8 9138' 3.831" 4-1/2" Otis Sliding Sleeve 9 9178' 3.75" XN Nipple 10 9210' 3.958" 4-1/2", 12.6#, L-80 Butt SCC Pup Joint 11 9225' Pressure Sub 12 9226' 800 HP (725 Series) ESP Assy FISH IN WELL: 1989: 4-1/2" TCP Gun Bull Plug = OD ?, .75" long. 6-19-1998: Schlumberger perf gun: 1-3/8"x19" MH-22, 1-11/16"x21" CCL, 2-1/S"x19.5" MPD, 2-1/2x42,5" Safe system, 2-1/2"x20' HC perf gun (fired), 2-1/2"x2" bull plug. = 31.8' total length (Tap 11,849 (+~), 2007 ESP WO -Cleaned out wellbore to 11,508' Reperfed G zone PERFORATION DETAILS Zone Condition To Bottom Len th G-2 6 SPF, 60-deg+ PJ Ome a Re erf 2/07 10,730.00 10,755.00 25.00 G-3 6 SPF, 60-deg + PJ Ome a Re erf 2/07 10,795.00 10,825.00 30' G-4 6 SPF, 60-deg + PJ Ome a Re erf 2/07 10,848.00 10,890.00 42' G-4 5 SPF, 4-1/2" PJ Ome a 2/21/07 10,893' 10,918' 25' B-1 6 SPF, 60 de 11,250.00 11,300.00 50.00 B-2 S ueezed 11,320.00 11,410.00 90.00 B-3 6 SPF, 60 de 11,435.00 11,495.00 60.00 B-4 6 SPF, 60 de 11,515.00 11,670.00 155.00 B-5 120-de hasin 11,695.00 11,850.00 155.00 B-6 120-de hasin 11,865.00 11,930.00 65.00 ROTATING 28" Drive Pipe - 37 hrs 20" Casing - 50.5 hn 13-3/8" Casing - 275.5 hrs 9-5/8" Casing - 246.5 hrs 7" Cosine - 73.5 hrs REVISED: 3/28/07 REVISED: BCA/CRW • •. CheVran Francisco Castro Chevron North America Exploration and Production ~^ Technical Assistant 909 W. 9th Avenue ~': ^s;; ~~::: Anchorage, AK 99501 ~'"~~~ ,w. Tele: 907 263 7844 Fax: 907 263 7828 E-mail: fcbn@chevron.com December 4, 2007 To: AOGCC Christine Mahnken 333 W. 7th Ave. Ste# 100 Anchorage, AK 99501 PERMIT# ~ AP'N'JP,IBER ~'~1'ELL ~LOGTI"PE T SCALE~LOGDATE ~ INTERS/AL RUN B- j FIL~A ~ CD ~ NOTES- ~ LODGED r L1NE ~ ! ,LAS, ~ i PDS. 1 ~ ~ ~ ~ DLIS ~ ~.- -- -- - --- - - - - -- - - - ~ - _--- COMPLETION RECORD 4.5" POWERJ ET 21-Feb- 167-080 507332006800 D-01 OMEGA 5 SPF 5" 07 9000 - 11448 1 1 1 1 PDS ULTRA SONIC IMAGER 1 ION AND 15 J 169-095 507332020300 D-20 CEMENT 5" 07 169 - 9456 1 1 1 1 PDS ~~.. s~~~~ D~~ ~` ~ 2°a~ s~ ~ ~lo~~~~a t,s ~ ~. ,~, ~. ~~ ~z Please acknowledge receipt by signing and returning one copy of this transmitta or FAX to 907 263 7828. Received By: Date: 1~'1t;l~br9~6 f\ A STATE OF ALASKA A ALAS~IL AND GAS CONSERVATION COMM~N REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon Repair Well Performed: Alter Casing D Pull Tubing D Change Approved Program D Opera!. Shutdown 0 2. Operator Union Oil Company of California Name: 3. Address: Plug Perforations Perforate New Pool 0 Perforate 0 4. Well Class Before Work: Development 0 Stratigraphic D Exploratory D Service D PO Box 196247, Anch, AK Stimulate Other.j CO & Rplcd ESP WaiverD Time ExtensionD Re-enter Suspended Well D 5. Permit to Drill Number: 167-080 6. API Number: 50-733-20068-00 9. Well Name and Number: Dolly Varden D-01 ' 10. Field/Pool(s): . McArthur River Fieldl Hemlock,4'~ O· 7. KB Elevation (ft): 39.1' Rig floor to DCB Tbg spool 8. Property Designation: 4 þ -r1 Dolly Varden Platform At)... , 1~' f t.J. ~ .0 11. Present Well Condition Summary: Total Depth Effective Depth Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: measured 12.071' true vertical 9,798' ons. Cnn-._. AnChorage w"",I/ssio feet feet Plugs (measured) n/a Junk (measured) 11,508' measured 11,508' true vertical 9372' feet feet Length Size 716' 20" 2527' 13-3/8" 9690' 9-5/8" 2492' 7" MD TVD Burst Collapse 715' 1530 psi 520 psi 2430' 3090 psi 1540 psi 7944' 5750 psi 3090 psi 9792' 8160 psi 7020 psi 716' 2527' 9690' 12,063' Measured depth: 10,730' - 11,930' sCANNED APR 0 5 2007 True Vertical depth: 8,764' - 9692' Tubing: (size, grade, and measured depth) 4-1/2" L-80 9225' Packers and SSSV (type and measured depth) nla 12. Stimulation or cement squeeze summary: Intervals treated (measured): NIA Treatment descriptions including volumes used and final pressure: Representative Daily Average Production or Injection Data Gas-Mcf Water-Bbl Casing Pressure 50 2850 1287 210 8293 120 15. Well Class after work: Exploratory D 16. Well Status after work: Oil0 . Gas D 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Prior to well operation: Subsequent to operation: 14. Attachments: Copies of Logs and Surveys Run Daily Report of Well Operations 13. Oil-Bbl 49 455 Tubing Pressure 357 120 Development 0 Service D x WAG D GINJ 0 WINJ D WDSPL Sundry Number or NIA if C.O. Exempt: 307-049 D Contact Chantal Walsh - 263-7627 Signature Printed Name Timothy Brandenburg Title Drilling Manager Phone 907-276-7600 Date 28-Mar-07 R , G , N fJ I RBDMS 8FL APR 04 2007 ~,'-\¿ .,~bmit Original Only k~ 1...: //Ý I(tro/.~ "·"3·'07 RKB = 39.10' Rig Floor to DCB TBG Spool Top Liner 9569' Fish @ 1l,849' 7" TD =12,063'; PBTD 11,998' ETD = 11,849'; 44.3 deg @ 3900' SIZE WT 20" 94# H-40 8 rd 716' 26" 13-318" 61# J-55 Butt 2527' 17W' 9-518" 40# N-80 Butt 4860' 9-5/8" 43.5# N-80 Butt 6315' 12-1/4 9-5/8" 47# N-80 Butt 8772' 9-518" 47# P-HO Butt 9690' Liner 7" 29# N-80 X-Line 9569' 12,063' 8-l/2" 820 sxs 9569' Tubin: 4.5" 12.6# L-80 Butt Mod see 3.958" Surface 9225' ,JEWELRY 1 2488' 3.833" 4-112" GLM RK Valve 2 4220' 3.833" 4-112" GLM #6, RK Latch and R-2 Valve 3 5649' 3.833" 4-112" GLM #5, RK Latch and R-2 Valve 4 6412' 3.833" 4-112" GLM #4, RK Latch and R-2 Valve 5 6988' 3.833" 4-112" GLM #3, RK Latch and R-2 Valve 6 7535' 3.833" 4-112" GLM #2, RK Latch an(l R-2 Valve 7 8110' 3.833" 4-112" GLM #1, RK Latch and R-2 Valve 8 9138' 3.831" 4-112" Otis Sliding Sleeve 9 9178' 3.75" XN Nipple 10 9210' 3.958" 4-112",12.6#, L-80 Butt see Pup Joint 11 9225' Pressure Sub 12 9226' 800 HI' (725 Series) ESP Assy 1989: 4-1/2" TCP Gun Bull Plug = OD?, .75" long. 6-19-1993' Schlumberger perfgun: J-3/8"xJ9" MH-22, J-]J/J6"x2J" CCL, 2-J/8"x19.5" MPD, S¡¡fe syst~m, 2-112"x20' HC p~rf bun pJug. 31.8' total length (Top J 1,849 (+/-). Zone DETAilS Bottom G-2 10,730.00 10,755.00 G-3 10,795.00 10,825.00 G-4 10,848.00 10,890.00 G-4 B-1 B-2 B-3 B-4 B-5 B-6 10,893' 11,250.00 11,320.00 11,435.00 11,515.00 11,695.00 11,865.00 10,918' 11,300.00 11,410.00 11,495.00 11,670.00 11,850.00 11,930,00 120-de '"\.UI 28" Drive Pipe 20" Casing 13-3/8" Casing 9-5/8" Casing 7" Casimr - 37 hrs - 50.5 hrs - 275.5 hrs - 246.5 hrs - 73.5 hrs Len tl1 25.00 30' 42' 90.00 60.00 155.00 155.00 65.00 REVISED: 3/28/07 REVISED: BCA/CRW Primary Job Type ESP Jobs Primary Job Type ESP Daily Operations 2/1/2007 00:00 - 2/2/2007 00:00 OP!!rations Summary Tubing punch from 9222-9228. 2/10/200700:00·2/11/200700:00 Operations Summary Skid rig to D-1. Prep rig. Mix sized salt. PJSM with production. Pump down tbg with returns to prod. well clean tank. . clean down, monitor for static losses. Well took 29 bbls. Break circ to well clean tanks. Returns at 55 bbls. Pumped satruated salt salt pill and 10 bbls spacer. Chase pill with 3% KCL FIW, pumped 25 bbls. Shut in annulus and bull headed 140 bbls. PJSM ND tree and inspect hanger. PU riser. NU BOPE. 2/11/200700:00 - 2/12/200700:00 Operations Summary NU BOPE. Verify VBRs. Test BOPE to 250 PSI low and 3000 PSI high. Pull BPV and install TWC and test blinds to 250 PSI low and 3000 PSI high. Pull TWC. BOP witness was waived by AOGCC. Screw in landing joint to hanger. Install TIW valve. Circ well taking returns to well clean tank. 2/12/200700:00 - 2/13/2007 00:00 Operations Summary Cont to circ to well clean tank. At 416 bbls had oily water returns. BO LDS and pull hanger to rig floor. Remove ESP pig tail, penetrator, LD landing joint and tbg hanger. Fill hole. 10 BPH losses. POOH w/ ESP completion. Cut out splices. Recovered super bands. Found splice at7307' is blown out Cable below megged. POOH to pump. PUall flat guards, protectolizers, superbands (2 more than in tally) and canon clamps (1 more than in tally). 2/13/2007 00:00 - 2/14/2007 00:00 Qperations Summary Laydown ESP seal section. Test motor - OK. UD motor and recover 62 cannon clamps, 5 flat guards, 6 protectorlizers and 33 bands (31 on tally). Pick up swivel and MU kelly. PU cleanout BHA. PU drillpipe. 2/14/200700:00 - 2/15/2007 00:00 Operations Summary Test kelly. Pick up and drift 5" drillpipe. RIH breaking circ until tagged at 9446'. Wash to 9564'. Circ bottoms up, and POOH. 2/15/200700:00 - 2/16/200700:00 Operations Summary POOH with 5" DP. LD CO BHA. Recover pieces of buckle and super band and scale. MU 5-3/4" BHA and RIH filling up at intervals, tagged at 9610'. Worked down to 9619'. 2/16/200700:00 - 2/17/2007 00:00 Operations Summary Washed and reamed from 9619' to 10382. Pumped hi-vis sweep. Continued to wash and ream to 10693. Pumped 15 bbl hi-vis sweep. Operations shut down due to EMD exhaust fire. 1 hour down time. Finished pumping hi-vis sweep around. Washed and reamed to 10967'. 2/17/200700:00 - 2/18/2007 00:00 Operations Summary Cleaned out 7" liner, running into hard spots and working through them, at 11,506' wgt increased and high torque was noted. POOH. 2/18/200700:00 - 2/19/2007 00:00 Operations Summary BHA pulled out of hole. Recovered 27" of control line, and 57" piece of control line, 2 bands, and 2 gallons of scale. Test BOPs, 250 psi low and 3000 psi high. PU BHA. RIH filling drillpipe every 2,500'. 2/19/200700:00 - 2/20/2007 00:00 Operations Summary Finish running in hole to 11,503'. Unable to clean out past 11,508'. Excessive torque. Spot 50 bbl sized salt pill, with 15 bbl spacers on either side. POOH and LD 5" DP. 2/20/2007 00:00 - 2/21/2007 00:00 Operations Summary PJSM. Displace wellbore with clean KCL fluid. TOH, laying down DP. 2/21/200700:00 - 2/22/2007 00:00 Qperations Summary POOH and LD 5" and 3-1/2" DP, drill collars, BHA. Clean out boot baskets. Recovered assorted peicesof bands, control lines, and scale. Had a 37" piece of control line. BHA was worn. PJSM. RU eline. Make correlation run. RIH and perforate with 4-1/2" PJ Omega 5 SPF guns. Shot first interval- G4 zone (10,893' - 10,918'). Lost 2.8 bbl of fluid to hole in first 30 min. Second shot interval - G4 zone (10,848 - 10,878). Lost 1.4 bbls in first 30 mins. 2/22/200700:00 - 2/23/2007 00:00 Operations Summary Continued perfing. Perfed G3 bench (10,795' - 10,820'). Lost 1/2 bbl fluid to hole. Perfed G2 (10,731' - 10,751 '). Lost another 1/2 bbl to well. POOH. RD Eline. Prep for running ESP equipment into well. PU ESP to RIH. Daily Operations 2/23/200700:00 - 2/24/2007 00:00 Op"rations Summary PU and RIH with ESP assymbly. Test Phoenix tool. Test chack.valves. Test cham inj lines.CheckprotectolizersODs. PJSIv1 ¡;'d~IHk'l¡th&9P'¡meg cablß every 1000ft. Pump control lines before and after each splice. 2/24/2007 00:00 - 2/25/2007 00:00 Op"rations Summary PJSM. Continue to trip in with ESP checking cable continuity every 1000 ft. Splice cable. Finish running in with ESP assembly. Base of ESP equipment at 9315'. PIU landing joint, MU hanger, install TWC. Run checks on all equipment. Land hanger. ND pitcher nipple and flow system and stack. 2/25/200700:00 - 2/26/200700:00 Op"rations Summary ND and remove bell nipple, break stack at riser. Break at DCB spool and lift riser above deck. Megged ESP at wellhead and checked out. PU and tested tree. Demobe rig 77. 2/26/200700:00 - 2/27/2007 00:00 Op"rations Summary Demob rig 77. 2/27/2007 00:00 . 2/28/2007 00:00 Op"rations Summary Demob 2/28/200700:00 - 3/1/2007 00:00 Op"rations Summary Demob 3/1/2007 00:00 - 3/2/2007 00:00 Op"rations Summary Demob .., MEMORANDUM . 5ta~f Alaska Alaska Oil and Ga~nservation Commission TO: Jim Regg (P.I. supervisOr)í<'etI? 3/7{ù 7 Petroleum Engineer l ¡ , DATE: March 1,2007 FROM: Lou Grimaldi Petroleum Inspector SUBJECT: No Flow Test .' Chevon/Dolly Varden Platform ,/' TBU 0-01 PTD#167-0800 McArthur River Field I verified the No-Flow Status Chevrons well 0-01 aboard the Dolly Varden platform in Cook Inlet. This verification was due to a recent workover John Lee (Lead Op.) did a good job preparing this well for the test and was accomodating with my requests. I arrived to find the well (Tubing/Casing) nearly bled off. As this is an ESP well there was not much gas to deal with and no , fluid production was present. The manifold was rigged approximately as I had previously requested, I did have the crew change j the gauge used to check pressure to 5" models which had a better resolution. The gauge used was a 60 psi 1/4 psi increment and the flow meter was a 200-2000 SCF ERDCO paddle type I observed the following; Time Notes: 1030 Flowing to Atmosphere >0 psi, <200 SCF/hour. 1050 Flowing to Atmosphere >0 psi, <200 SCF/hour, Shut well in for buildup. 1110 S.I. @ 1 psi r 155 S.I. @ 1.5 psi, Open well to flow meter. Initial flow 1500 SCF/hour 1157 Flowing @ 1200 SCF/hour. fJ'¡"~' 1200 Flowing @ 800 SCF/hour. '\ 1205 Flowing @ <200 SCF/hour. 1210 Flowing @ Whisper. 1220 Flowing @ bare whisper. Shut-in well 1230 S.I. @ >0 psi 1235 S,I @5 psi 1240 SI @.5 psi 1250 SI @ 75 pSI 1255 S.I. @ 1 pSI 1310 S.I. @ 1.25 psi 1315 S.I. @ 1..5 psi 1320 S.I. @ 1.75 psi 1325 S.I.@1.75psi 1330 S.I. @ <2 psi 1335 S.I. @ <2 psi 1340 S.I. @ <2 psi Open well to flow meter, initial flow @ 1800 SCF/hour. 1341 Flowing @ 1500 SCF/hour & 1.75 psi 1342 Flowing @ 1300 SCF/hour & 1.5 psi ",'¡'..i' 1343 Flowing @ 1000 SCF/hour & 1.25 psi \V\ 1344 Flowing @ 700 SCF/hour &.5 psi 1345 Flowing @ 600 SCF/hour & .25 psi 1347 Flowing @ 300 SCF/hour & >0 psi 1355 Flowing @ 200 SCF/hour & >0 psi 1400 Flowing @ Whisper & 0 psi 1410 Flowing @ Whisper & 0 psi 1420 Flowing @ Whisper & 0 psi 1430 Flowing @ Whisper & 0 psi 1530 Flowing @ Whisper & 0 psi /1600 No Flow of gas present I concluded the test at this point. This well appears to be incapable of unassisted flow to surface. ::;:~\:;ANNED MAR t 'i 2.OI'J7t Leuer ~..fo ~fR-l(Jcv- q Pfò\J i Ì'ëj ~/u,/) vJ¿ ð:f!- S5'; V 2007 -0301_No-Flow_ TBU _D-01Jgxls . . SARAH PALIN, GOVERNOR AI·A.SHA. OIL AlQ) GAS CONSERVATION COMMISSION 333 W. 7th AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Timothy Brandenburg Drilling Manager UNOCAL PO Box 196247 Anchorage, AK Re: McArthur River Field, Hemlock Oil Pool, D-O 1 Sundry Number: 307-049 r¿V \\1 Y ~ &CANNED FEB 1 2 2007 Dear Mr. Brandendurg: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, DATED this ~ day of February, 2007 Encl. æ.7"o1 STATE OF ALASKA _ A_ .¡ _ ALA~OIL AND GAS CONSERVATION COM~N f\? APPLICATION FOR SUNDRY APPROVALS '{ tA:: I V'ED o 5 2007 1. Type of Request: Abandon D Alter casing D Change approved program D 2. Operator Name: Union Oil Company of California 3. Address: PO Box 196247, Anchorage, AK Suspend D Repair well D Pull Tubing 0 . 20 MC 25,280 Operational shutdown D Plug Perforations D Perforate New Pool D 4. Current Well Class: Development 0 Stratigraphic D 'Hê<!'£i 1m J<? f" ~ Perforate 0 . Waiver q?·''''.JUIIS. :n_" r? Stimulate D Time Extension d~¡"Ç:t~lftii8 failed ESP Re-enter Suspended Well D Cleanout wellbore 5. Permit to Drill Number: Exploratory 0 167 -080 Service 0 6. API Number: 50-733-20068-00 8. Well Name and Number: 7. If perforatÎng, closest approach in pool(s) opened by this operation to nearest property line where ownership or landownership changes: Spacing Exception Required? Yes 0 9. Property Designation: Dolly Varden Platform 12. Total Depth MD (ft): 12,071' ., Casing Structural Conductor 716' Surface 2527' Intermediate 9690' Total Depth TVD (ft): 9798' . No 0' 0-01 10. KB Elevation (ft): 11. Field/Pool(s): AD c... t'7 $'1" Ii" .".1·Ø? 39.1' Rig floor to DCB Tbg Sp McArthur River Field/Hemlock, G-zone ,... PRESENT WELL CONDITION SUMMARY Effective Depth MD (ft): Effective Depth TVD (ft): 11,849' 9743' Size MD Plugs (measured): n/a Junk (measured): 11,849' Length TVD Burst Collapse 13-3/8" 9-5/8 " 716' 2527' 9690' 715' 2430' 7944' 1530 psi 3090 psi 5750 psi 520 psi 1540 psi 3090 psi 20" Production Liner 2494' Perforation Depth MD (ft): 10,730' - 11,930' Packers and SSSV Type: n/a 13. Attachments: Description Summary of Proposal 0 Detailed Operations Program D BOP Sketch 0 15. Estimated Date for 7" 12,063' 9792' 8160 psi 7020 psi Tubing MD (ft): 9239' Perforation Depth TVD (ft): 8,764' to 9,692' Tubing Size: Tubing Grade: L-80 4-1/2" 17. Verbal Approval: Commission Representative: 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Printed Name Timothy C. Brandenburg Title Drilling Manager _._ '7' Signature ?-- ( .......... /C ^ ~~.~qpê 907-276-7600 /'" ~ Date: Packers and SSSV MD (ft): n/a 14. Well Class after proposed work: Exploratory 0 Development 2/10/2007 16. Well Status after proposed work: Oil 0 Gas D WAG D GINJ D 0 . Service 0 D Abandoned D D WDSPL D Commencing Operations: Plugged WINJ Contact Chantal Walsh 263-7627 Date 2 -5- 07 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: { ?fJ 1- O.lf OJ P'" """'> 0 BOP Tos' jš.. . Meoh,"loa"ole9''> Too' 0 lo~tlO' C~,",oœ 0 ~ Other: ~O...f(?\'",^,-'"\'''''''''::H''''''' ~\?\.t."'>~ t ~~\-,,~c::.<>~ ~\9~\O~~C),~\~J ~\~, t" ð-~~. '> c ~ ~ '>';" ",,-,< ~ Q..-.:> 'ð '" <-v.. 0 '" . S'bS""e~::~~ .... I ">-e=- 't::."':>" <Jo.:)Ooc\="'<:s;- "'01..",,-, RBDMS 8Ft FER ¡ 21007 Form 10-403 Revised 06/2006 f¡ Û~MMISSIONER V V ;E#R7009 APPROVED BY THE COMMISSION Date: 1..g",1fJ.., Approved by: ORfGINAL Submit in Duplicate A ~{ .,/$p ~·1·ÇÞ1 ,~~;.~ . . 0-01 ESP Repair Objective: / Pull and replace the failed ESP, Cleanout the wellbore, Reperforate the G Zone. Procedure: c::c c> ,"" \ _ \. . '" ">-~~C>Q\~\\\ 1 MI/Spot and RU Eline. Test BOPE's ~\""'L"\'--,,)~\"~~ Q.~'-..)~ ~~ \ \ '......\r<-,.)'O...~ \ \ 'r I 2 MobeRigontoD-Ol. ~;coaÇ'c,.\ ~~~""\,)~ Yo1'vJ\ per 3 Set BPV, ND tree. NU BOPE. Test same Pi- ;)1 '" <..,~o..\."::."~ 4 Remove BPV. PUMU Land joint. BO LDS. PU tbg hngr to rig floor. Remove tbg hngr. ') 5 Cont POOH wi tbg. Stand Back tbg. LD ESP equipment. 6 PUMU 5" drillpipe and clean out BRA for 9-5/8" casing (bit/string mill/bootsubs). RIH and clean out to top ofliner, CBU, POOH. Stand back 5" DP and LD BHA. Circ and spot LCM pill as required, 7 PUMU 3-1/2" Drillpipe (to cover cleanout of 7" liner) x-over to 5" DP and Clean out BHA for 7" using a reverse junk basket to remove fish from hole. CBU. POOH, Stand back drillpipe and LD BRA. Circ and spot LCM pill as required. 8 PUMU 3-1/2" drillpipe to cover 7"liner) x-over to 5" DP and Clean out BHA for 7" casing (bit/string mill/bootsubs). RIH and clean out to at least 11,700'. CBU. POOH. LD drillpipe and BHA. 9 Cire and spot LCM pill as required. 10 RU Eline. Perforate G Zone intervals (4 runs). .;' Bench Interval Footage G-2 10733' - 753' G-3 10797' - 822' G-4 10850' - 880' G-4 10895' - 920' 11 RD Eline. 12 Land tubing with eontrolline and cable spliced through hanger. LID landing joint and RID tbg tools. Install BPV, 13 NID bell nipple. NID BOPE & Riser. N/U adaptor & tree. Pull BPV, Install TWC and Shell test tree. Turn well over to production, 14 Demobe well 25' 25' (10800'-810' is new) '" 30' 25' (new) .;' n-01 Table RKB '" 40.30' ¡ Btm of Trolly beam 4.59' 11.92' 18.23 To of drill deck A 21116" 8M HCR Valve B 2 1116" 8M Manual gate valve C 2 1116" 8M Manual gate Kill line D 2 1116" 5M Manual gate Kill line E 3 118" 5M Target Tee 18,20 to tbg spool F 21116" 5M Target Tee 22.23 RKB = 39.10' Rig Floor to DCB TBG Spool 11,849' 7" TD =12,063';PBTD n,998' ETD = 11,849'; 44.3 deg @ 3900' H-40 8 rd Surface 716' 26" 1600 sxs Surface J-55 Butt Surface 2527' 17 !/Z" 21 00 sxs Surface N-80 Butt Surface 4860' N-80 Butt 4860' 6315' 12-114 2066 sxs Surface N-80 Butt 6315' 8772' P-IlO Butt 8772' 9690' N-80 X-Line 9569' 12,063' 8-1/2" 820 sxs 9569' 12.6# L-80 Butt Mod see 3,958" Surface 9239' 1 2 3 4 5 6 7 8 9 10 11 2492' 4071' 5474' 6237' 6904' 7485' 8060' 9239' 9271' 9281' 9282' 3.833" 3.833" 3.833" 3.833" 3.833" 3.833" 3.833" 3.813" 3.598 4-112" GLM #7, RK Latch and R-2 Valve 4-1/2" GLM #6, RK Latch and R-2 Valve 4-112" GLM #5, RK Latch and R-2 Valve 4-112" GLM #4, RK Latch and R-2 Valve 4-112" GLM #3, RK Latch and R-2 Valve 4-112" GLM #2, RK Latch and R-2 Valve 4-112" GLM #1, RK Latch and R-2 Valve XN Nipple 4-112",12.6#, L-80 Butt see Pup Joint Pressure Sub 800 HP (725 Series) ESP Assy 1989: 4-1/2" TCP Gun Bull Plug = OD?, .75" long. 6-19-1998: Schlumbergerperf gun: 1-3/S"xI9" MH-22, I-I 1I16"x21" CCL, 2-I/S"xI9.5" MPD, 2-1/2x42,5" Safe system, 2-1I2"x20' HC perf gun (fired), 2-1/2"x2" bull plug. ~ 31.S' total length (Top 11,S49 (+/-). 2006 ESP WO - 2.91' anode and I super band. Might be some sections oftlat gaurds. PERFORATION DETAilS Zone T (II) Bottom Length 6 SPF, 60-deg G-2 phasino 10,730,00 10,755.00 25.00 6 SPF, 60-deg G-3 phasino 10,810.00 10,825.00 15.00 6 SPF, 60-deg G-4 phasino 10,850.00 10,890.00 40.00 B-1 6 SPF, 60 deo 11,250.00 11,300.00 50.00 B-2 Soueezed 11,320.00 11,410.00 90.00 B-3 6 SPF, 60 dea 11,435.00 11,495.00 60.00 B-4 6 SPF, 60 deq 11,515.00 11,670.00 155.00 B-5 120-deo phasino 11,695.00 11,850.00 155.00 B-6 120-dea ohasina 11,865.00 11,930.00 65.00 28" Drive Pipe 20" Casing 13-3/8" Casing 9-518" Casing 7" Casine: , Hj '.H~.' - 37 hrs - 50.5 hrs 275.5 hrs - 246.5 hrs - 73.5 hrs REVISED: 1/25/07 REVISED BY: BCA Re: Dolly D-Ol 403 Special Request . . Chantal, There should not be a problem with moving to D-Ol. I understand the desire to keep costs as low as possible. One item you should probably check is how Conservation Order 351 A applies in this case. Certain activities on production and injection wells do not require a sundry prior to beginning the work. In Chevron's case, I think the requirement to submit a sundry is only when you are going to start work on a platform where such operations haven't been active. A report of the work is still required. Please check the CO. There is no problem with applying for with a sundry at any time, but I think the CO does give you all some relief in this case. Call or message with any questions. Tom Maunder, PE AOGCC Walsh, Chantal-Petrotechnical [contractor] wrote, On 2/6/2007 10:21 AM: Tom, We are currently having good luck with the 0-47 pull/replace ESP workover (I guess repeating the same drill over and over seems to help). Additionally, we had 0-01 fail a week and a half ago. We are in the process of getting partner approval to move directly to 0-01 after the completion of 0-47 and take advantage of the lower mobe costs, if we can get approval from you. I dropped off the 403, for 0-01, yesterday. Is it at all possible to get this request through your agency in an unrealistic short time frame? Apologies for this inconvenience, Chantal 263-7627 SCANNED fEE 1 2. 2007 1 of 1 2/7/20073:06 PM RECEIv!O MAY 1 5 700H Union Oil.pany of California 909 W. 9th ue Anchorage,Ä 99501 Tele: (907) 263-7889 E-mail: oudeand@chevron.com Fax: (907) 263-7828 Chevron , .~...~ " .... _I' ":) C\)Hii!\\¡~"" Debra OudeqO~ì,.1\ 01\ & (.h~A~1I1 . Technologist JI.)(tli){ð{j<I To: AOGCC Helen Warman 333 W. ih Ave. Ste#100 Anchorage, AK 99501 '196-013 ! 507332047000 ! GP54 i 204-186 '-~. ....-...... 502312002800 'HAPPY VALLEY- A10 Date: May 11, 2006 ''''n·,~\&>,\~\.~i;;¡í i. ~\)..~\,.~-\.\" ¥t;¡¡¡íiI~ .....:. C' :" (;.. · MUL TlFINGER IMAGING . .,!ºº~.. ...." · COMPLETION RECORD 2' · OMEGA HSD 6SPF · pds · pds,txt i 51NCH . 15-Apr- ........L...Q6............ : 5 INCH 11-Dec- 05 ! 45-3000 : 1 '0 ......-.,-..,......-........."...---..-... : 7250·8020 .....--¡. ,204-207 ; 502312002900 , ...... ~ ......_........ . .........' , c...·.. __.._....", .,....___.__......"".,...____....... ."....___.....,...., ,.......,...__... HAPPY VALLEY- . HALLIBURTON MAGNA CIBP ! A 11 : SETTING RECORD 5 INCH 16-Noy- . 6720-7190 : 05 pds . 1 :204-207 í 502312002900 THAPPYVÄ[[Ëy~mT 2.5 POWERGET HSD GUN / . fSÎNCH . 16-Noy- '6830-6990 : 2 · A 11 . PERFORATION RECORD : 05 ~-.. .... .... - , ," ..... ....... . 204-207 . 502312002900 i HAPPY VALLEY· : A11 ~ _"." u_ ____._ _ ".... ...___.. . .....,.., 199-054 501331012501 · SCU 21A-09 190-147 507331005501 TBF A-01RD 167-080 !SÓ7332ÓÓ6SÓO · TBU D-01 198-064 507332026701 · TBU G-21RD í 169-086 507332049800 TBU G-32 ..., COMPLETION RECORD : 51NCH . 10-NoY- , HALLIBURTON CIBP FOR 3.5' · i 05 , CASING /2.5 HSD POWER , JET 6 SPF PERF · pds, txt 7990-9085 ·COMPI..ËTIONRËcÖFïO¿.5 . 1SINCH' : 01-May- 10095- OMEGA HSD 6 SPF ' 06 10450 1 , pds .,....................,.....----.. COMPLETION RECORD 2 · HSD POWER JETS 4SPF 51NCH . 02-Feb- ,5300-6015 , 06 pds icÒMPl..ËtlÒNFïËcÒFïOà3l8 i 51NCH . 11-Feb-'!!2SÓ:!!4i4 '1 : HSD POWER JET 6 SPF, 60 . 06 PHASING · pds · COMPLETION RECORD 2.25 : 51NCH : 29-Jan- ,9615-9833 · POWERJET HSD GUNS, 4 ¡ 06 : SPF, 60 DEG, GAMMA RAY / CCL CORRELATION , pds, pdt , 1 · COMPLETION RECORD 2.875 . 51NCH 31-Jan- : 9180-9950 · POWERJET HSD GUNS, 4 06 ¡ SPF, 60 DEG, GAMMA RAY / : CCL CORRELATION ¡ pds, pdt Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to (907) 263-7828. I Rece;ved By, C.1t----- I Date, S--!~¡">' STATE OF ALASKA ALAS.IL AND GAS CONSERVATION COMMeON REPORT OF SUNDRY WELL OPERATIONS RECEI'JED MAR 0 3 2006 3. Address: PO Box 196247, Anchorage, AK 99519 Plug Perforations Perforate New Pool D Perforate D 4. Current Well Class: Development [] Stratigraphic D Stimulate s L~~sion EŠ'P'....·- chorage 1. Operations Abandon Repair Well .¡ Performed: Alter Casing D Pull Tubing [] Change Approved Program D Operat. Shutdown D 2. Operator Union Oil Company of California Name: Al8ska<of~ WaiverD Time Extension Re-enter Suspended Well 5. Permit to Drill Number: 167-080 ~ 6. API Number: 50-733-20068-00 9. Well Name and Number: ExploratoryD ServiceD 7. KB Elevation (ft): 106' RT above MSL 8. Property Designation: Dolly Varden Platform/Cook Inlet 11. Present Well Condition Summary: D·01 " 10. Field/Pool(s): McArthur River Field/G-Zone, Hemlock Total Depth Effective Depth measu~ed 12,071' " _ feet. _....... ;.~ true vertlcal~ ~78Z feet j¡.~~/¿j,¿'.". it l .. Ii!"}) ...~" /__ ;), ~<.J' Plugs (measured) n/a Junk (measured) n/a Casing Structural Conductor Surface Intermediate Production Liner measured 11,998' feet true vertical 9,727' feet Length Size MD TVD 716' 20" 716' 715' 3,043' 13-3/8" 3,043' 2,826' 9,690' 9-5/8" 9,690' 7,944' 2,494' 7" 12,063' 9,792' Burst Collapse 3,090 psi 5,750 psi 1,540 psi 3,090 psi 8,160 psi 7,020 psi Perforation depth: Measured depth: 10,730 to 11,930' True Vertical depth: 8,764 to 9,692' Tubing: (size, grade, and measured depth) 4-1/2", 12.6#, N-80 @ 9,271' Packers and SSSV (type and measured depth) n/a 12. Stimulation or cement squeeze summary: Intervals treated (measured): n/a Treatment descriptions including volumes used and final pressure: RBDMS 8Ft MAR () 6 2D06 13. Representative Daily Average Production or Injection Data Gas-Mcf Water-Bbl Casing Pressure 702 1,913 1220 197 7,058 120 15. Well Class after proposed work: ExploratoryD Development [] 16. Well Status after proposed work: Oil[] Gas D WAG D 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Prior to well operation: Subsequent to operation: 14. Attachments: Copies of Logs and Surveys Run Daily Report of Well Operations Oil-Bbl 103 580 Tubing Pressure 540 120 Service D x GINJ D WINJ D WDSPL D Sundry Number or N/A if C.O. Exempt: 305-384 Contact Larry W. Buster 263-7853 Printed Name Timothy C. Brandenburg Signature Title Drilling Manager Date ~S ,-I-~ Submit Original Only K~~ Well Name D-01 Primary Job Type ESP Jobs QC Eng Daily Operations 2/2/200600:00 - 2/3/2006 00:00 Operations Summary Start Rig Mobilization 2/3/200600:00 - 2/4/200600:00 Operations Summary Continue Rig Mobilization. Offload equipment. 2/4/2006 00:00 - 2/5/2006 00:00 Operations Summary Rig Mobilization. 2/5/200600:00 - 2/6/2006 00:00 Operations Summary Rig Mobilization. 2/6/200600:00 - 2/7/2006 00:00 Operations Summary Rig Moblization. 217/200600:00 - 2/8/2006 00:00 Operations Summary Mix sized salt pill and 3% KCL. Line up to circulate well with 3% KCL. 2/8/200600:00·2/9/200600:00 Operations Summary Circulate well with 3% KCL. Pump into place sized salt LCM pill. N/D Tree. N/U BOPE. 2/9/200600:00 - 2/10/200600:00 Operations Summary Continue to N/U BOPE. Test BOPE to 250/3000 psi. Conduct rig drills. Circulate well with 3% KCL. 2/10/200600:00 - 2/11/2006 00:00 Operations Summary Pull tubing hanger. POOH with failed ESP completions. 2/11/200600:00 - 2/12/2006 00:00 Operations Summary UD ESP assembly. RlU Schlumberger and test lubricator to 1,500 psi. RIH and unable to pass 9,453' with 3-3/8" guns (scale build-up at ESP motor setting depth). POOH. RID Schlumberger. 2/12/200600:00 - 2/13/2006 00:00 Operations Summary RlU ESP assembly. RIH with new completion. 2/13/200600:00 - 2/14/2006 00:00 Operations Summary Run ESP completion. P/U and land tubing hanger. N/D BOPE. 2/14/200600:00 - 2/15/2006 00:00 Operations Summary Continue to NID BOPE. N/U and test tree to 300/5000 psi. Start to demob rig. 2/15/200600:00 - 2/16/2006 00:00 Operations Summary RD/MO. D-01 McArthur River 50-733-20068-00 O¡lwell 12,071'/9,772' Operator: Zone Permit: RKB: PBTD/PBTVD: Unocal Alaska k, G-Zone 167-080 106' RT above MSL 11,998'/9,727' Grade Type Top (FT) Btm (FT) Length (FT) H-40 0.00 716.00 716.00 BTC 0.00 3,043.00 3,043.00 N-80 BTC 0.00 4,860.00 4,860.00 TC 4,860.00 6,315.00 1,455.00 TC 6,215.00 9,690.00 3,475.00 C-KC 9,569.00 12,063.00 2,494.00 Tubin Size Type Top (FT) Btm (FT) Length (FT) BTC-Mod 0.00 9,271.00 9,271.00 No. 1 2 3 4 5 6 7 8 9 10 11 12 Type 11" x 4-1/2" CIW OCB BTC Tbg Hgr (top and bottom) 1/2" GLM #7, RK Latch and R-2 Valve 1/2" GLM #6, RK Latch and R-2 Valve 4-1/2" GLM #5, RK Latch and R-2 Valve 4-112" GLM #4, RK Latch and R-2 Valve 4-1/2" GLM #3, RK Latch and R-2 Valve 4-1/2" GLM #2, RK Latch and R-2 Valve 3.833 4-1/2" GLM #1, RK Latch and R-2 Valve 3.813 XN Nipple 3.958 4-112", 12.6#, L-80 8TC SCC Pup Joint 800 HP (725 Series) ESP Assembly Aiumnium Anode (end of assy) Perforation Detail Zone G-2 G-3 G-4 8-1 B-2 B-3 8-4 8-5 B-6 Condition 6 SPF, 60-deg phasing 6 SPF, 60-deg phasing 6 SPF, 60-deg phasing 120-deg phasing Squeezed Top (FT) Depth 39.10' 4,071 5,474' 6,237' 6,904' 7,485' 8,060' tm (FT) Length (FT) 10,755.00 25.00 10,825.00 15.00 10,890.00 40.00 11,300.00 50.00 11,410.00 90.00 11,495.00 60,00 11,670.00 155.00 11,850.00 155.00 11,930.00 65.00 I Last Revised: IDED 12/27/2006 I Revised By: RE: Dolly Varden D-l Perforations e e Subject: RE: Dolly Vardcn D-I Perforations From: "Buster, Larry \\''' <Ihustcr@unocal.com> D~1te: Fri, 03 Feb 2006 16:32:42 -0900 \ <0 'ì. -' 0 ~() To: Thomas Maunder <totll_maunder@admin.statc.ak.us> cc: "Brandcnburg, Tim C" <bral1denburgtC£:~')un()cal.com>, "Harness, Evan" <eharncss@unocal.coJ1l> Tom, We will comply to these conditions as outlined. We will contact both you and Jim Regg when we are ready to conduct the "No-Flow" Test. Thank You, Larry Buster Drilling Engineer Union Oil Company of California -----Original Message----- From: Thomas Maunder [mailto:tom maunder@admin.state.ak.us] Sent: Tuesday I January·_m·3··1··~··········2"6'õ"6····"·3··;···07 PM ........... ........._h__............ To: Buster, Larry W Cc: Jim Regg Subject: Re: Dolly Varden D-1 Perforations Larry, By reshooting and adding perforations to this well, a new no-flow test will need to be conducted. In the past an arbitrary "within 60 days" period was allowed for performing the new no-flow. In addition to the no-flow, this work likely requires the testing of the SSV when the tree is reinstalled. Unocal should determine and notify myself and Jim Regg as to when the testing can be accomplished. You all have much more information regarding well performance to make such determination. If the well does not satisfy the no-flow criteria, then Unocal will need to make an application to operate the well without a SSSV. This action would require notice and a hearing. Good luck with the work. .<"\ ë)' '?í1f!R Tom Maunder, PE U {j Cd)J AOGCC Buster, Larry W wrote, On 1/17/2006 3:59 PM: Tom, With reference to the upcoming ESP workover on the Dolly Varden Well D-1. The 10-403 (Sundry Number 305-384) was submitted and approved without mentioning our desire to re-perforate several G-Zones. The proposed intervals we would like to perforate are as follows: G-2: 10,730' - 755' 25' (re-perforate of existing perforations) G-3: 10,800' - 825' 25' (10,800' - 810' is additional new holes in casing) G-4: 10,855' - 885' 30' (re-perforation of existing perforations) G-4 : 10,895' - 922' 27' (additional new holes in casing) I have attached a PDF file of the G-Zone intervals. As I mentioned in out phone call, the G-4 addition from 10,895' - 922' is the zone that is capped by a conglomerate break. To ensure this is not a isolated sand package, we have reviewed surrounding wells where this sand package is perforated. Our geologist can trace the sand signature and concludes these zone has been produced from and should have a pressure similar to the G-4 zone already perforated from 10f2 2/7/20069:26 AM RE: Dolly Varden D-l Perforations e e 10,855' - 885'. I have attached a PDF file of the G-Zone intervals for your review. We are planning to start this work the first week of February. Thanks and Regards, Larry Larry Buster Drilling Engineer Union Oil Company of California «G Zone Interval Well D-1.pdf» 2 of2 2/7/2006 9:26 AM ~- ~ /" ~ \ - - - ~ -=t - - . II! T - -¿, 1 p0/ . .. . . . . · .' '~~'¥:-J\~,...t. V'V' \ .\--- ~ -- ~ -../ ~ ~~ <,:_, .;¡ <;;-~ ').§ ~ ~. _t,~ 1_1= 2.- ~- . - . - J! w: wdE2é \.1 .lL-T 11 -4 ~ '-1 IV --"':::::... ..-¡....... ~ -~~- ~ ~IY iœlØ!lllBl ,._...11 I I 10800 ---------¡---- 10900 ----r~-.- I '.l¡rl.... .. ..l'.' ..' ........ .. .'. ..... .... .. ". ". <;0"'1. . '7 ....... -6 ( ;....... l.I'~·············· .·.¡·=t····.·······i .····.··.·.·.·.·.·..!·······I~··· .......)t......J............~....'.'...'J." .....~.. "[ \ .~... ..,"no,," ..' ,___ - c·n .. --- .' . . . - - .... - --- -- -~ . ..... ....... ---' ' ..... . ---1-.,..--...---'-- _I ........ ............... .... .' ! ..... .' ·fl.: . .. -..------,.-. - . ....,------------.---- -- . .. . ..... - --- ---. ..___ .n___n . I ___'.n.... I '1-- i ; . I . I I ') / : ~ ~~~J'9 ;~~~ -8800 -- ==! -~ I C' ;2(= "I 'Ç,J ~ I ~ . .' . ~IYI "- '-tl~ í'l11~1-..t .. ---_... -,- l '--TW- 11QOO ...-1 -8900 I ¡'j". . ·1 ..·f·..· . 'i ___J I tn'" ~)b éFv ~1f!A\1fŒ e (IT1 fb jh\ n 11¡J'UI ,,-n!1 '~ !LJ U~ e 1'fù ~ 'j+.. ", t1 i j 1~' !"':"'ì In,A\, ¡ u \ LJlI 1. '. " 1/ ;1 <j , ~ FRANK H. MURKOWSKI, GOVERNOR AItASIiA. OIL AND GAS CONSERVATION COMMISSION 333 W. 7TH AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Timothy C. Brandenburg Union Oil Company of California P.O. Box 196247 Anchorage, AK 99519 ...'-:...Õ-'.;'....-. _lbí/VbV Re: McArthur River D-O 1 Sundry Number: 305-384 S{;ANJ~t:f . '),","'" 2 1 ILUUJ Dear Mr. Brandenburg: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. Please provide at loost twenty-four (24) hours notice for a representative of the Commission to witness any required test. Contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, DATED this /6day of December, 2005 Encl. 1. Type of Request: _ STATE OF ALASKA ALA~ OIL AND GAS CONSERVATION COMMeoN APPLICATION FOR SUNDRY APPROVALS 20 MC 25.280 Suspend Operational shutdown Repair well ~Æ~ Plug Perforations D Pull Tubing ~ \"')\'Þerforate New Pool D 4. Current Well Class: ~?-{, Iø RECEIVED Development Stratigraphic ission Abandon Alter casing D Change approved program D 2. Operator Name: Union Oil Company of California 3. Address: [] D Service Exploratory D D 6. API Number: 50-733-20068-00 ~ PO Box 196247, Anchorage, AK 99519 7. KB Elevation (ft): 106' RT above MSL 8. Property Designation: Dolly Varden Platform 11. Total Depth MD (ft): 12,071' 9. Well Name and Number: 0-01 10. Field/Pools(s): McArthur River Field/Hemlock, G-Zone PRESENT WELL CONDITION SUMMARY Casing Structural Conductor Surface Intermediate Production Liner Total Depth TVD (ft): 9,772' Length Effective Depth MD (ft): Effective Depth TVD (ft): 11,998' 9,727' Plugs (measured): n/a Junk (measured): n/a Collapse Size MD TVD Burst 716' 3,043' 9,690' 20" 716' 3,043' 9,690' 715' 2,826' 7,944' 3,090 psi 5,750 psi 1,540 psi 3,090 psi 13-3/8 " 9-5/8" Perforation Depth MD (ft): 10,730 to 11,930' Packers and SSSV Type: 2,494' 7" Perforation Depth TVD (ft): 8,764 to 9,692' n/a 12,063' Tubing Size: 4-1/2" 9,792' Tubing Grade: 8,160 psi 7,020 psi Tubing MD (ft): 9,316' L-80 n/a 12. Attachments: Description Summary of Proposal Detailed Operations Program D BOP Sketch [] 14. Estimated Date for Commencing Operations: ../ 13. Well Class after proposed work: Exploratory D Development [] 15. Well Status after proposed work: 1/15/2006 Oil D Gas D Plugged tJ WAG D GINJ D WINJ D Service D Abandoned D D 16. Verbal Approval: Commission Representative: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Printed Name Timothy C. Brandenburg Title Drilling Manager Date: WDSPL Larry Buster 263-7853 Signature Phone 907-276-7600 COMMISSION USE ONLY Date 1'&- ~-OS' Conditions of approval: Notify Commission so that a representative may witness Sundry Number: -384 Plug Integrity D BOP Test I)( Mechanical Integrity Test D Location Clearance D Other: '3c)O~c;:\ \3>0 Ç> .~'".>~ C. '> \' \~~~(t~. ~ \ \ ~C,\¿", \ '" CJ.~ ~ f . '-.J "-<XÄ. \ ~<s? \ÑO k.o '-JQ:. '" OÇ>Cc:.\"'C.. ~O f'-.. S -\> ~ ù ~ . COMMISSIONER APPROVED BY THE COMMISSION Date: /ÿ ,,/6,. () ( Form 10-403 Revised 07/2005J 0 R , G' N A L RBDMS 8Fl DEe 1 9 2005 Submit in Duplicate hnical.Schematic Dolly Varden Platform, D-01 Revised 4/16/03 DED Casing and Tubing Detai I 2 Size Weight Grade Conn 20" 94 H-40 13-3/8" K-55 9-5/8" 40 N-80 9-5/8" N-80 4 9-5/8" 47 N-80 Liner 7" 29 L-80 BTC-KC 6 4,116 5,234 6,109 6,737 7,242 8 7,751 9 9,316 10 9,347 11 9,348 12 9,453 3.833 3.833 3.813 3.958 12.6 * DV collar @5,856' 7 Jewelry 9 10 11 12 Perforation l-80 BTC-Mod o 800 HP (725 Series) ESP Assembly Aluminium Anode (end of assembly) PBTD @ 11,998'; TD 12,063' Condition PF 6O-degree phasing 6 SPF 6O-degree phasing 6 SPF 6O-degreephasing 12Q.-degree phasi ng Squeezed O--degree phasing phasing 12O-degree phasing Table 10.90' 40.23' 15.58' 18.92' A 41/16" 5M Foster HCR Valve B 41/16" 5M Manual gate valve C 31/16" 5M Manual Gate Kill line D 31/16" 5M Manual Gate Kill line 135/8" 5M x 11" 5M Cross over Spool 22.31' Top 11.92' e Dolly Vardl Platform Well D-l ESP Repair OBJECTIVE: Replace the failed ESP assembly currently in Well D-l. PROCEDURE SUMMARY: 1. Shut off gas lift gas. Bleed down SIWRP slowly to avoid damaging ESP cable. 2. If unable to circulate thru pump. Then punch holes in tubing above ESP. 3. Circulate oil out of annulus and load well wi 3 % KCL. 4. Activate Dolly Varden Rig. 5. Spot sized salt pill (if necessary) to manage losses and keep hole full while POR and while RIR wi tubing and ESP assembly. 6. Set BPV and N/D tree on Well D-l. N/U BOPE . Test 13-5/8" BOPE (see attached diagram) to 25013,000 psi. 7 . Verify well dead. 8. POR wi tubing, cable & failed ESP. Visually inspect tubing & LID singles while POR. Send failed ESP equipment & unusable tubing to shore. 9. RIH wi replacement ESP assembly similar to the current failed completion (see attached diagram). 10. Install BPV. N/D BOPE. N/U & test tree. 11. Install flow line and surface facilities & turn well over to Production. 12. Startup ESP confirm it is functioning properly. AOGCC D-l ESP Workover Summary 1 of 1 December 15,2005 ~KA OIL AND GAS CONSERVA~ION C0P~IISSION FRANK H. IVlURKOWSKI, GOVERNOR 333 W. 7TM AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Dwight Johnson UNOCAL Field Superintendent PO Box 196247 Anchorage, Alaska 99519 RE: No-Flow Verification TBU Well D-1 PTD 167-080 May 15, 2003 Dear Mr. Johnson: On May 8, 2003 AOGCC Petroleum Inspector Lou Grimaldi witnessed a "no-flow" test on Well D-1 at UNOCAL's Dolly Varden Platform, Trading Bay Unit, McArthur River Field. Mr. Grimaldi arrived on Dolly Varden Platform and observed the well flowing with zero pressure, making no fluid and with a measured gas rate of 200 scf/hr. The well was shut in for 80 minutes and the tubing pressure was measured to be 2 psi as observed on a 100-psi gauge. The well was opened to flow for 20 minutes with an initial measured gas flow noted of 600 scf/hr that fell to 300 scf/hr in 4 minutes. The well was SI for 30 minutes with 2 psi observed again and an initial measured flow of 275 scf/hr decreasing to below the meter threshold of 180 scf/hr in 2minutes. A third build up and flow cycle yielded similar results. Throughout the observation period no liquid flow was observed. The observed performance of TBU well D-1 (167-080) demonstrated that the well is incapable of unassisted flow of hydrocarbons to the surface. It has been concluded that TBU well D-1 (167-080) meets the criteria of a "no-flow" performance test and as such, is considered incapable of unassisted flow to the surface. The well's performance meets the criteria at 20 AAC 25.265 (b). Therefore the well is not required to have a fail-safe automatic SSSV, however, the pilot and SSV must be maintained in satisfactory operating condition. If for any reason the well again becomes capable of unassisted flow of hydrocarbons, the SSSV must be returned to service. A copy of this letter should be maintained in the respective well file on board Dolly Varden. Sincerely, Thomas E. Maunder, PE Sr. Petroleum Engineer (' STATE OF ALASKA ( ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown: Stimulate: Plugging: Perforate: x Pull tubing: x Alter casing: Repair well: Other: Add G-Zone/Run ESP 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB) Union Oil Company of California (UNOCAL) Development: X 106' RT above MSL feet 3. Address Exploratory: 7. Unit or Property name Stratigraphic: P.O. Box 196247 Anchorage, AK 99519-6247 Service: Trading Bay Unit 4. Location of well at surface Leg A-2, Conductor 1 8. Well number 755' FSL & 1126' FWL Sec. 6, T8N, R13W, SM D-1 At top of productive interval 9. Permit number/approval number 505' FSL & 3243' FWL Sec. 32, T9N, R13W, SM 67-80/303-028 At effective depth 10. APl number 852' FSL & 3586' FWL Sec. 32, T9N, R13W, SM 50- 733-20068 At total depth 11. Field/Pool 885' FSL & 3620' FWL Sec. 32, T9N, R13W, SM McArthur River Field 12. Present well condition summary Total depth: measured 12,071' feet Plugs (measured) true vertical 9,772' feet Effective depth: measured 11,998' feet Junk (measured) true vertical 9,727' feet Casing Length Size Cemented Measured depth True vertical depth Structural Conductor 716' 20" 1600 sx 716' 716' Surface 2527' 13-3/8" 2100 sx 2527' 2430' Intermediate 9690' 9-5/8" 2066 sx 9690' 7929' Production Liner 2494' 7" 820 sx 12,063' 10,077' Perforation depth: measuredRECEIVED see attached true vertical APR 2 3 2003 see attached Tubing (size, grade, and measured depth) 4-1/2" 12.6# L-80 BTC MOD to 9,347' Alaska 0il & Gas Cons. Commission Packers and SSSV (type and measured depth) Anchorage none 13. Stimulation or cement squeeze summary none Intervals treated (measured) none Treatment description including volumes used and final pressure none 14. Representative Daily Avera,qe Production or Iniection Data OiI-BBL Gas-Mcr Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 576 408 2791 115 94 Subsequent to operation 202 360 2498 779 150 15. Attachments: Schematic X 16. Status of well classification as: Copies of Logs and Surveys run: Daily Report of Well Operations: X Oil: X Gas: Suspended: Sew, j,~:---_ .,,_ ,.,. 17. I hereby certify that the foregoing is true and correct ,o the best of my knowledge: ~bCbiVEu APR ..2;,,~ .Z.003 ,,_.~ Alaska Oil & Gas Cons. Commission Anchorage Signed: & /~ [/~. Title:. Drilling Engineer Date: 4/21/2003 Form 10-404 Rev 06/15/88 DUPLICATE · Attachment #1 Trading Bay Unit Dolly Varden Well D-1 Form 10-404 4/21/03 Perforation Summary Formation G-2 G-3 G-4 HB-I HB-2 HB-3 HB-4 HB-5 HB-6 MD 10,730' - 10,755' 10,810'- 10,825' 10,850' - 10,890' 11,250'- 11,300' 11,320'- 11,410' 11,435'- 11,495' 11,515'- 11,670' 11,695'- 11,850' 11,865'- 11,930' TVD 8,763'- 8,786' 8,828'- 8,841' 8,860'- 8,892' 9,160'- 9,199' 9,213'- 9,282' (Squeezed) 9,301'- 9,347' 9,362'-9,481' 9,500'- 9,616' 9,627'- 9,675' DollyVarden Platform, D-01 last' revised 4/16/03 by Diane Dunham, Unocal Alaska 12 Size 20" We_~ht 94 Grade H-40 Conn Top_ 0 Btm 716 13-3/8" 61 K-55 BTC 0 3,043 9-5~8" 40 N-80 BTC 0 4,860 9-5/8' 43.5 N-80 BTC 4,860 6,315 9-5/8' 47 N-80 BTC 6,315 8,772 P-110 BTC [ 8,772 9,690 DV Collar at 5,856' 9-5/8"i 47 Liner 7" J~ 29 4-1/2" I 12.6 L-80 L-80 BTC-KC i 9,569 BTC-Mod I 0 12,063 9,316 Jewelry 453 ID 3.833 3.833 Item 11" x 4-1/2" BTC Tb_9 Hgr 4-~1/2" GLM #1, RK Latch and R-2 Valve 4-1/2" GLM #2, RK Latch and R-2 Valve 3.833 4-1/2" GLM #3, RK Latch and R-2 Valve 3.833 3.833 3.833 3.833 3.813 3.958 4-1/2" GLM #4, RK Latch and R-2 Valve 4-1/2" GLM #5, RK Latch and R-2 Valve 4-1/2" GLM #6 RK Latch and Oriface Valve 4-1/2" GLM #7 RK Latch and Dummy Valve X-Nipple 4-1/2", 12.6#, L-80 BTC SCC Pup Joint 60___00 HP (725 Series) ESP Assembh/ Alu~mnium Anode (end of assembly) Perforations Zone Top TD Bottom TD Condition G-2 10,730' 10,755' 6 SPF 60-degree phasing G-3 10,810___~' .10,.825' 6 SPF 60-degree phasing G-4 10,850' i10,890' 6 SPF 60-degree phasing B-1 11,250' j l 1,300' 120-degree phasing B-2 11,320' '11,410' Squeezed B-3 11,4351 1,495 O-degree phasing B-4 11,515' 11,670' 120-degree phasing B-5 11,695' 11,850' 120-degree phasing ....... B-6 11,865' i11,930' 120-degree phasing Unocal Alaska Business Unit Drilling Department Dolly Varden Well D-1 ESP Conversion Daily Summary 3/7/O3 Skid rig to the D-1 slot. R/D the flowlines and prep to N/D tree. 3/8/03 Insall BPV and N/D tree. N/U BOPE and test to 250/3000 psi OK. M/U landing joint and unseat tubing hanger. 3/9/03 Monitor well for losses. Pull and L/D 4-1/2" x 3-1/2" tubing completion. 3/10/03 Continue to L/D tubing. M/U spear assembly to recover PBR. RIH. 3/11/03 Engage spear and POOH with no recovery. M/U same fishing BHA and RIH to 11,068'. POOH. 3/12/03 Finish out of the hole with full PBR recovery. M/U packer retrieving tool (PRT) and RIH to 11,087'. Mill on packer while circulating 3% KCL (8.6 ppg) and POOH with partial recovery of PRT. 3/13/03 Suspend operations due to high wind conditions. 3/14/03 M/U overshot fishing BHA. RIH to 11,060' and wash over fish. POOH with full PRT fish. M/U new PRT BHA and RIH. 3/15/03 Tag packer at 11,042' and mill on same. POOH with no recovery. 3/16/03 RIH with new PRT BHA. Tag packer at 11,089' and mill on same. Chase packer to 11,102'. POOH with no recovery. M/U RTTS and RIH setting at 476'. Test same to 1,000 psi. N/D BOPE. 3/17/03 Continue N/D BOPE and tubing spool. 250/3000 psi OK. M/U spear and RIH. Install new tubing spool. N/U and test BOPE to Unocal Alaska Business Unit Drilling Department Dolly Varden Well D-1 ESP Conversion Daily Summary (Continued) Page 2 3/18/03 RIH with spear to 11,372' while chasing packer. POOH with full packer recovery. M/U 6" clean-out BHA. 3/19/03 RIH with clean-out assembly to 11,692' with 3% KCL (8.6 ppg). POOH and start to M/U TCP guns. 3/2O/O3 Finish P/U TCP guns and RIH to depth. Correlate with E-Line on depth and fire same with a drop bar. 3/21/03 Reverse clean with 3% KC1 (8.6 ppg) and POOH. R/U to run ESP completion. 3/22/O3 Run ESP completion on 4-1/2" tubing. 3/23/03 Continue to run ESP completion to 9453'. P/U and land and test tubing hanger. BOPE. N/D 3/24/O3 Finish N/D BOPE. N/U and test tree and release rig. Unocal Alaska 909 W. 9th Avenue Anchorage, AK 99501 Tele: (907) 263-7651 Fax: (907) 263-7828 E-mail: hamsonb@unocal.com UNOCAL Beverly Harrison Business Ventures Assistant April 15, 2003 To: AOGCC Lisa Weepie 333 W. 7m Ave. Ste#100 Anchorage, AK 99501 DATA TRANSMITTAL - 10000- D-01 TOP CORRELATION HALLIBURTON 4 5/8" CARRIER 5 INCH 3/20/2003 10569 2 1 1 U-05 COMPLETION RECORD 2.5" HSD POWER JET 5 INCH 3/22/2003 3570-3870 2 1 1 Please acknowledge receipt by signing and returning one copy of this transmittal or ~X~I~68. Received By.'~~i)~,'~q~,v~,..(,.v~~Date: ~PPt '["~' 2005 Alaska 0i'i & Gas Cons. Commiae~n ~chor~je MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: THRU: Dan Seamount, Commissioner '7 · Blair Wondzell, P. I. Supervisor FROM: John Crisp? ~ ~. SUBJECT: Petroleum In~¢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 cc; N:ON"CONFIDENTIAL SVS Dolly Plt. 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 Data. " ' Pilots SV SSV .~. ~ Well Type. Well Permit Separ Set L/P Test Test Test Oil, WAG, GIN J, Number Number PSI PSI Trip Code Code Code GAS or CYCLE I~ 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 80 80 P P OIL D-05RD 1800650 110 80 100 P P 43 OIL D-07RD2 1921550 110 80 80 P P P OIL D-08RD 1740030 110 80 75 P P P OIL D-II 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 110 80 90 P P OIL D-25RD 1780870 110 80 100 P P OIL D-26RD 1981290 110 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 1.700370 110 80 75 P P P OIL D-40RD 1'820830 110 80 80 P P OIL D-42 1830530 110 80 701 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% [--] 90 oar Remarks: Wells that have SSSVs out for repair are designated 43 & not counted as failures or components tested. 6/27/00 page 1 of 1 SVS Dolly Plt. 6-22-00jcl TONY KNOWLE$, GO VEF/NOR ALASKA OIL AND GAS CONSERVATION COMMISSION 3001PORCUPINE DRIVE ANCHORAGE. ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: t907) 276-7542 Deccmbcr 22. 1998 Chris Meyers\Dwight Jolmson Field Supcrintcndcnts UNOCAL 260 Caviar Street Kenai, Alaska 99611 Re; No-Flow Vcrification MRF Wells D-1 and M-29 Gentleman: Our Inspector, Louis R. Grimaldi. witncsscd "no-flow" tests on UNOCAL's McArthur River Field wclls D-I (PTD 67-080) and M-29 (PTD 91-027). Whcn the inspcctor arrivcd, thc wclls had bccn "in tcst" with no fluid production, but were now shut-in. The pressures wcre 4 to 6 psig; when open to atmosphcrc they blcd down immediately. He observed the wells shut-in for an hour - the pressurc built to 2 psig on cach well. They bled down rapidly in a buckct and had onh' thc slightcst gas flow. Thc inspector rccommcnds the wells bc granted "no-flow" status. McArthur River Field wells D-1 (PTD 67-080) and M-29 (PTD 91-027) meet the criteria ora "no-flow" performance test and as such arc considered incapable of flow to the surface. Under the authority of 20 AAC 25.265(A) they arc not required to have a fail-safe automatic SSSV; however, the pilot and surface safety valve must be maintained in good condition. If for anv reason, the well(s) again becomes capable of unassisted flow of hydrocarbons, the subsurface safety valve must be rmnstallcd and maintained tn good working ~ondition. Sincerely, Blair E. Won~zelC~~ PI Supervisor Attachments Lou Grimaldi Mark Atkins\Bill Smith - Dolly Varden Gary Ross - Steelhcad Dan Williamson - Anchorage bew/nt:d I +m29 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: David Johnston, DATE: Chairman THRU: FILE NO: Blair Wondzeil, ~ P. I. Supervisor FROM: Lou Grimaldi,~o.~. SUBJECT: Petroleum Inspector December 13, 1998 1UEJLMFE.DOC No-Flow test Unocal D-1 Trading Bay Unit PTD # (> 1 - o8 c> Sunday, December 13, 1998; I witnessed the well test exhibiting No-Flow status on Unocal well #D-1 (Dolly Varden platform) in the Trading Bay Unit. I had been in contact with Marc Atkins (Foreman) last month during SVS testing and scheduled the test for this time frame. I talked to Marc this morning on the status of the well. It has been in test with no fluid production and a small amount of gas working out of the fluid. I arrived to find the well shut-in with 4 psi on the tubing and casing (using a 60 psi gauge) which had been jumpered together. I had Joel Nelson (Unocal operator) open the well to the clean-up tank (.5 psi head) which bled the tubing pressure to 0 psi immediately. I observed the well for fluid production and finding none had the well shut- in. Over a hour the well slowly built to 2 psi and bled off rapidly when opened to the clean-up tank. I had the bleed down hose removed and ran into a bucket, I observed only the slightest of gas flow. I recommend this well be granted No-Flow status. SUMMARY: I witnessed Unocal well D-1 in the Trading Bay Unit exhibit inability to flow unassisted. Attachments: D-1 well test report. Cc; Chris Meyers\Dwight Johnson (Unocal Kenai) Mark Atkins\Bill Smith (Dolly Varden platform) NON-CONFIDENTIAL ., Unocal North America~ Oil & Gas Division Unocal Corporation P.O. Box 190247 Anchorage, Alaska 99519-0247 Telephone (907) 276-7600 UNOCAL~ Alaska Region DOCUMENT TRANSMITTAL July 29, 1993 TO: Larry Grant FROM: Kirk Kiloh LOCATION: 3001 PORCUPINE DRIVE ANCHORAGE, AK 99501 ALASKA OIL & GAS CONSERVATION COMM. LOCATION: P.O.BOX 196247 ANCHORAGE AK 99519 UNOCAL TRANSMITrING AS FOLLOWS TRADING BAY ,UNIT 1 blueline and 1 sepia each of the following open hole logs: TBU D-48 ~, s.c, c~/~ ~,~ ~r R E C E / VE b. ~/G~T Directional Survey (Floppy Disk) 0' - 10873'MD, 7/02/93 AUG 02 1~93 TBU D-1 '~~il &AnchorageSaS Cons. Cemmi~lon FBSB/PTS/GR/CCL 6/06/93 D~{~a THERMAL DECAY TIME LOG 6/04/93 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RE~G ONE COPY OF THIS DOCUMENT RECEIVEI) BY: DATF~: Unocal North Ameri~' 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, G ush Regional Drilling Manager GSB/lew DOL'LY DISTANCE & DIRECTIONS FROM SE CORNER SEC. 6, T8N, R13W CONDUCTOR LEG #A-1: LAT = 60048' 28.272" LONG =151°37' 57.620" "Y" COORD. "X" COORD. WELL # FSL · , 2,490,836.22 208,461.20 757.5 FWL 1212 0 1 2,490,836.95 208,454.55 D-27 758.1 1205.5 2 2,490,840.99 208,456.66 D-28 762.1 1207.4 3 2,490,842,79 208,460.79 D-29 764.0 1211.5 4 2,490,841.51 208,465.11' D-32 762.9 1215.8 5 .2,490,837.76 208,467.60 D-40 759.2 1218.4 6 2,490,833.28. 208,467. l0 D-41 754.7 1218.0 7 2,490,830.18 208,463.83 D-26 751.5 1'214.8 8 2,490,829.90 20B,459.34 D-25 & RD 751'.1 1210.3 9 2,490,832.58. 208,455.72 753.7 1206.7 0 2,490,835.56 208,458.66 D-24 & 34A 756.8 1209.5 1 2,490,838.66 208,462.17 D-31 & RD 760.0 1213.0 2 2,490,B34. O0 208,462.61 D-24A 755.3 1213.5 LEG #A-2' 2,490,835.42 208,381.20 754.7 2,490,836.16 208,374.66 . D-1 755.3 2,490,840.19 208,376.67 D-17 759.4 2,490,842.00 208,380.80 D-11 761.3 2,490,840.72 208,385.11 D-7 & RD 760.1 2,490,836.97 208,387.60 D-9 756.4 2,490,832.49 208,387.10 D-19 751.9 2,490,829.39 208,383.84 D-23 748.8 2,490,829.11 208,379.34 D-21 748.4 2,490,831.78 208,375.72 ' D-5 & RD 750.9 '2,490,834.77 208,378.66 D-15 & RD.& 2 754.0 2,490,837.86 208,382.17 D-3 & RD 757.2 2,490,833.21 208,382.61 D-13 752.5 2,490,756.22 208,462. O0 677.5 LEG fiB-l' LAT = 60048' 27.485" LONG =151°37' 57.564" 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 1 2,490,755.48 208,468.53 D-8 & RD 677.0 1221.4 2 2,490,751.45 208,466.53 D-6 672.9 121'9.5 3 2,490,749.65 208,462.40 D-14 & RD 671.0 1215.4 4' 2,490,750.92 208,458.08 D-20 672.1 1211.1 5 2,490,754.67 208,455.59 D-16 675.8 1208.5 6 2,490,759.15 208,456.10 D-22 680.3 1208.9 7 2,490,762.25 208,459.36 D-2 & A & RD 683.5 1212.1 8 2,490,762.53 208,463.85 D-4 683.9 1216.5 9 2,490,759.86 208,467.48 D-10 681.3 1220.2 10 2,490,756.87 208,464.53 D-12 & RD 678.3 1217.4 ll . 2,490,753.78 208,461.02 D-18 675.1 1213.9 12 2,490,758.43 208,460.58 D-30 & RD 679.7 1213.4 LEG #B-2' 2,490,755.43 208,382.00 674.8 (Reserved for Compressors) 1134.9 WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL [~, GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number UNOCAL (Marathon 0il Co. Sub-operator) 67-80 3. Address 8. APl Number P. 0. Box 190247 Anchorage, AK 99519 50- 733-20068-01 4. Location of well at surface Leg A-2, Cond. #1 Dolly Varden Platform 9. Unit or Lease Name 755' FSL, 1,126' FWL, Sec. 6 8N-13W-SM Trading Bay Unit At Top Producing Interval 10. Well Number 505' FSL, 3,243' FWL, Se~. 32 9N-13W-SM D-1 At Total Depth 11. Field and Pool 885' FSL, 3,620' FWL, Sec, 32 9N-13W-SM McArthur River Field 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. 106' KB above MSL I ADL 17594 Hemlock Pool 12. Date Spudded 13. DateT,D. Reached 14. Date Comp.,Susp. orAband. I15. Water Depth, if offshore 116' No' of Completions 12/19 / 67 2120 / 6g 2/10/89 I 132feet MSL I ]. 12,071' - 9772' 11,998' - 9727' YES• NO[]/( 325' feetMD N/A 22. Type Electric or Other Logs Run Nnn~ 23. CASING, LINER AND C'EMENTING RECORD SETTING DEPTH MD CASINGSIZE WT. PER FT. GRADE TOP BOTTOM HOLESlZE CEMENTING RECORD AMOUNT PULLED 20" 93# H-40 0' 7!6' 26" 1600 sx C!~ e. N/A l'~_q/9" ~1~ ,I_EI:; f1~ ? ~;97' 17-1/9" 711111 ~ C.I~ G N/A cl_~/R" tr~ lt'~ ~; N_Rfl fl' q Rqfl! 12-114" ?flC;g .~ Cl**~ e. N/A ~ ~l~ '~ ~ '~ "' ~ ~ ~ ~ ...... i 47# P-110 7" Pq~/ N-Rfl ql:;t~q~ l?_flRq' R-l/?" R?~l .v nl~<, c. N/A 24. Perforations open to Production (MD+TVD of Top and Bottom '*nd 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) B-1 8 SPF 120° phasing 4.5" 9,513' B-2 Squeezed 3.5" 11,178' 11,103' B-3 4 SPF 0© phasing 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. B-4 8 SPF 120° phasing DE'PTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED B-5 " " " B-6 " " " . 11,O34' - 11,420' lb sx Class "G" Cement See Attachment #1 for Per# Intervals 27. PRODUCTION TEST Date First Production Method of Operation (FloWing, gas lift, GTC,) 1/29/89 Gas Lift Date of Test Hours Tested PRODUCTION FOR OIL-EEL GAS-MCF WATER-EEL CHOKE SIZE GAS-OIL RATIO 2/26/89 12 TESTPERIOD I~ 108 ,', 18 796 NA 167 Flow Tubing Casing Pressure CALCULATED OIL-EEL GAS-MCF WATER-EEL OIL GRAVITY-APl (corr) Press. 150 1200 24-HOUR RATE ~ 217 37 1591 34° @ 60°F 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. None Form 10,407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 29. · 30. GEOLOGIC MARKERS .. FORMATI'ON TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Hemlock 11,252' 9,161' None , 31. LIST OF ATTACHMENTS , Attachment #1, Current' Perforated Intervals; Attachment #2, Current Wellbore Diagram 32. I hereby certify that the foregoing is true and correct to the 'best of my knowledge . · . Environmental .. . Sign ~x~,~ Title' i~,ng-lneer . ' Date 04/06/89 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 (muitiple completion), so state in item 16,'and.in item 24 show the pr,oducing intervals'for only. the interval reported in item 27. Submit a separate form for each additional interval to be separately 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- Bench Attachment #1 TBU Well D-1 Perforations MD 11,255' - 11,295' 11,320' - 11,410' 11,435' - 11,495' 11,515' - 11,670' 11,695' - 11,850' 11,865' - 11,930' TVD , , 9,163' - 9,194' 9,213' - 9,282' (Squeezed) 9,301' - 9,347' 9,362' - 9,481' 9,500' - 9,616' 9,627' - 9,675' NEF/em/60/Sundr4 Attachment #2 MARATHnN FIIL CDMPANY TRADING BAY UNIT ~/ELL D-1 20' Csg 94# H-40 E 716' 01/31/89 Att measuremen.ts are RKB 'to .top o~ equlpmen% 40.5' Cameron 4.5· 'DC]3' Tbg Hngr. 325' D.tls 4.5' Series lO Ball Type SSSV w/pups. 0'-9513' 4.5' 12.6#, L-80, AB Mod Bu.t.t Tbs. 9513'-9516' 4.5' x 3.5' XD. 951G'-11,178' 3.5· 9.3#, EU£ 8rd, L-BO AI~ Hod ~u~ Tbs. 'Gas U~'.t mandrels 1-7 are 4,5° Ftope~crot SPM-P w/AB Mod Bu~c.t couplings. Mandrels 8-10 are Camco MMG-II w/AB Mod EUE 8rd couplings. Valves are gAMELq 1.5· R-2O w/ RK La.tches. Valve ~[0 Is oPl~lce ~ype, 13-3/8' Csg 61# K-55 E 3,043' TDL 7' E 9569' 9-5/8· gs9 4~ 43.~ 47# N-80 & P-110 Cs9 ~ 9690' - 7' Csg 29# N-80 la12,063' 2477' #1 16/64' 4588' #2 16/64' 6075' #3 20/64' 7080' #4 24/64' 7777' #5 24/64' 8436' #6 24/64' 9011' #7 E~0/64' 9610' #B 20/64' 10,176' #9 20/64' 10,74~' #10 24/64' 11,087' lt,088' 11,103' 11,113' 11,145' 11,178' B-1 B-1 B-E B-3 B-4 B-3 B-6 B-4 PBT9 E 11,998' TI) E 12,063' Baker Seal AssembLy Loca.tor & seal assembly (12.78'). Baker- PBR w/'CH' Anchor' Lo,.tch. 7'% 29# Baker-grown 3H Perm Pkr (4.00' I3) w/mlU, ou.t exi;enslon. 4.5' x 3.5· XD (LTE Box x EUE Brd). Iq.tls 'XN· Nipple. l~aker Shearou.t Sub w/~/L re-en.try guide. Per?ora.tlons 11,255'-11,295' 8 SPF 11,320'-11,410' 4 11,435'-11,495' 4 11,515'-11,670' 8 11,695'-11,850' 8 11,865'-11,930' 8 120' Phas~n9 01/89 Squeezed · O' Phasing 10/69 120' Phasing 01/89 · · · · · , ;,~i, laska.Oi] .& Gas Cons~ Commissio~ :, Anchoraga Revision ~a.te~ 3/20/89 Revised By, MRD/ne¢ Reason, OLV Changes Previous Revision, 2/7/89 STATE OF ALASKA ( ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown __ Pull tubing ~ Alter casing __ Repair well __ 2. Name of Operator I 5. Type of Well: v Uf'!0CAL (Marathon Oil Company - Sul:l Opera~t~Pm.ent'' / ~xp~oratory __ 3. Address / Stratigraphic __ P. 0. Box 190247 Anchorage, AK 9~519 Service, 4. Location of well at surface Leg A-2 ¢ond. #1 uoiiy Varden Pla'cform Stimulate__ Plugging__ Pedorate X Other __ 6, Datum elevation (DF or KB) 106' KB above MSL Unit or Property name Trading Bay Unit 8. Well number 755' FSL, 1,126' FWL, Sec. At top of productive interval 505' FSL, 3,243' FWL, Sec. At effective depth 852' FSL, 3,586' FWL, Sec. Att°tald8e6~n"" FSL, 3,620' FWL, Sec. 6 - 8N - 13W - SM 32 - 9N - 13W - SM 32 - 9N - 13W - SM 32 - 9N - 13W - SM D-1 9. Permit number/approval number 8-537 10. APl number 50-- 733-20068-01 11. Field/Pool Hemlock feet 12. Present well condition summary Total depth: measured true vertical 12,071' 9,772' feet Plugs (measured) feet None Effective depth: measured 11,998 ' true vertical 9,727 ' Casing Length Structural Conductor Surface 2,527' Intermediate 9,690' Production Liner 9,569' Perforation depth: measured feet Junk (measured) feet Size Cemented 13-3/8" 2,100 sx 9-5/8" 2,066 sx 7" 820 SX true vertical See Attachment #1 Tubincl (siz~e.~g, rade. and measured del:)th) 4-1/2",3}2.6~{ L-80 3-1/2 , 9.3#, EUE 8rd, L-80 Tbg 951 - ,178' Packersand SSSV(type and measured depth) 7", 29# Baker-Brown Otis 4-1/2" Series 10 BV-SCSSV @ 325' MD 32' of perf gun @ approx 11,865' Measured depth True vertical depth AB Mod. MD . 3H 2,527~. . 2,419' 9,69(~ECE, ~~ 7,929' 12,063.,~ ,-),. ' Tbg ~ 9,5~3' HD; Perm Pkr (4.0"ID) @ 11,103' MD; 13. Stimulation or cement squeeze summary Intervals treated (measured) See Attachment #2 "Summary of Daily Operations" Treatment description including volumes used and final pressure 14. Representative Daily Average Production or Injection Data OiI-Bbl Gas-MCf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 11/23/88 46 Subsequent to operation 2/26/89 217 17 720 1240 120 37 1591 1200 150 15. Attachment¢: Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: Oil X Gas__ Suspended __ Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. SignedForm 10-40"~4 ~Va/~'06'15'88?'/~ E)~'*"¢'"'/~ Title Environmental Engineer Date04/06/89 SUBMIT IN DUPLICATE Bench Attachment #1 TBU Well D-1 Perforations MD 11,255' - 11,295' 11,320' - 11,410' 11,435' - 11,495' 11,515' - 11,670' 11,695' - 11,850' 11,865' - 11,930' TVD 9,163' - 9,194' 9,213' - 9,282' (Squeezed) 9,301' - 9,347' 9,362' - 9,481' 9,500' - 9,616' 9,627' - 9,675' NEF/em/60/Sundr4 Attachment #2 Well D-1 Daily Summary of Well Operations 01/01/89 01/02/89 01/03/89 01/04/89 01/05/89 01/06/89 01/o7/89 01/08/89 01/09/89 01/10/89 01/11/89 Accepted rig from D-30RD2 @1200 hrs 12-31-88. Moving rig tools from Rig 76 to Rig 77. Filling annulus w/ FIW. Continue RU Rig #77. Fill annulus on D-1 w/ FIW. RU chiksans from tree to floor. Cont RU. Pump 140 bbl 3% KC1 into annulus. Well on vacuum. Mix and spot 40 bbl lite-sal down tbg. Displace w/ 170 bbl 3% KC1. Press inc. from 0 to 275 psi. RU to pump down annulus. Reverse to clean well tank. Circ to clean well tank. Monitor well. Set BPV. ND tree. NU BOPE and function test. Change PR's to 4½". Test BOPE 250/2500 psi, annular 20/1500 psi. Fill tbg and annulus (8 bbl). Unseat tbg hanger. Work tbg and unseat PKR. Circ. Monitor well. POOH w/ 5 jts. Circ and work pipe free. POOH. LD tbg. POH, LD tbg and GLM's. Install 5" PR's. Test to 250/2500 psi. MU BHA. RIH and PU DP. PU 5" DP and RIH. Wash 11,650'-11,700'. Hydromatic leaking. Wash and ream 11,700'-11,815'. Clean out sand. Some torque from top of fish. POH 6 stds. Removing hydromatic for repairs. Remove hydromatic. Repair same. Replace hydromatic. RU floor. POH w/6" bit. Boot baskets full of perf debris. MU 1 jt wash pipe and overshot. RIH. Wash 11,800'-11,815'. Push fish to 11,845'. Washed junk around wash pipe. Work pipe free. Single out to TOL. POH. LD wash pipe. RIH w/ OS and cutlip guide. PU DP & RIH. W/R 11,823'-11,869'. Latch fish and pulled loose. POH. Recovered 11.5' x 2-1/8" perf gun. Junk baskets full. RIH w/O.S. Latch fish unable to work free. Release O.S. Pipe free. Latch fish. Unable to work fish free. Release O.S. POH. Junk baskets full. Testing BOPE. Test BOPE to 250/3000 psi. Annulus 250/1500 psi. PU 4-3/8" O.D. burnshoe O.S. and extension. RIH. Washover fish 11,874'-11,887'. Engage fish. Circ. POH. Recovered Well D-1 ~ Daily Summary of Well Operations Page 2 01/12/89 01113189 01/14/89 Ol/15/89 01/16/89 01/17/89 01/18/89 01/19/89 01/20/89 remainder of perf gun. LD fishing tools. MU 6" bit & boot baskets. RIH. Wash and clean out fill 11,851'-11,973'. Wash fill 11,975'-11,998'. Circ. POH. PU 8-1/2" bit and 9-5/8" scraper and RIH to 9565'. POH. RIH w/6" bit and 7" scraper. Work 7" csg scraper thru perfs to 11,430'. CBU. POOH. R/U and run CET and csg insp log ll,998'-surface. P/U 7" RBP and 9-5/8" RTTS and RIH. Set 7" RBP @ 11,200'. Test csg, liner lap and 7" liner to 11,200' to 2000 psi. OK. R/U and set 9-5/8" RTTS @ 9500'. Test csg to 2500 psi. OK. Release RBP. POOH. RU E-line. RIH and set EZSV at 11,420'. MU 7" Champ PKR and RIH. Set PKR at 11,034'. Mix and squeeze 75 sx Class "G" w/additives to 3000 psi. POOH 5 stds. Reverse out. Set PKR. Hold 2000 psi on squeeze. WOC. POOH w/7" RTTS and RIH w/6" bit to 11,000'. CBU. WOC. RIH tag at 11,078'. Drill cmt 11,078'-11,233' still soft, WOC. Drill cmt 11,233'-11,415'. CBU. CBU. Test csg to 2000 psi. Drill cmt 11,415'-11,439' to EZSV retainer. Test csg to 2000 psi. Lost 50 psi in 20 min. Displace hole w/filtered inlet water. Drill retainer at 11,439'. Push to 11,996'. Displace hole w/filtered 3% KC1. Fin displacing hole w/filtered 3% KC1. POOH. MU 675' of 4-1/2" TCP gun, PKR, pressure gauges and RA tag. RIH. Fill 63 stds w/FIW for cushion, 1000 psi under balance. RIH. Correlating w/GR-CC1. Correlate TCP guns. Set PKR @ 11,131' DPM. Fire guns to perforate. Good blow in bucket. Fluid level dropped in annulus. Fill annulus. Hole taking 18 bph. Unseat PKR. RO 235 bbl. POOH 8 stds. Attempt to spot 30 bbl Lite-sal pill. DP plugged. POOH. Keeping hole full. LD RA tag, gauge carriers, PKR, 3 jts of bent 3-1/2" DP and firing head. Left 668.77' of 4-1/2" TCP gun in hole. LD 18 jts. bent DP. WO fishing tools. MU overshot, extension,, bumpersub, jars. RIH. Tag @ 11,304'. Wash down 3'. Could not get past 11,307'. Pull 2 stds. Spot polymer pill. POOH. POOH w/overshot. Recovered 10 sections of 4-1/2" TCP gun. (254.4' total) TOF @ 11,558'. Test BO?E 250/3000 psi. Annular (250/1500 psi). MU fishing BHA. RIH. Engage fish @ 11,556'. POOH. LD 9 sections of 4-1/2" TCP gun and blank Well D-1 Daily Summary of Well Operations Page 3 01/21/89 01/22/89 01/23/89 01/24/89 01/25/89 01/26/89 01/27/89 01/28/89 02/09/89 02/10/89 (228.96' total) TOF @ 11,785'. 8 sections of gun remaining. Perforations at: Bench #1 11,255'-11,295' 40' Bench #4 11,515'-11,600' 85' Bench #5 11,695'-11,850' 155' Bench #6 11,865'-11,930' 65' 22.7 gram charges 8SPF @ 120° phasing. MU spear and RIH. Engage fish @ 11,785'. POOH. Recovered 1 carrier (25.44'L) TOF @ 11,810'. Redress spear and RIH. Engage fish @ 11,810'. POOH. Recovered 1 carrier (22.44'L) TOF @ 11,833'. LD fish. 6 carriers left in hole. LD fish. RIH w/spear. Engage fish @ 11,833'. POOH. Recovered 1 carrier (22.44'L) Redress spear. RIH. Engage fish at 11,863'. POOH. Recovered 1 carrier (22.44'L) Redress spear and RIH. RIH w/spear. Engage fish @ 11,888'. POOH. No recovery. Redress spear. RIH. Engage fish at 11,888'. POOH. Recovered 4 carriers. Left bullnose in hole. MU bit and boot baskets. RIH. RIH w/6" bit. Wash fill 11,982'-11,992'. Tagged junk @ 11,992'. CBU. POOH. PU 7" csg scraper and RIH. Work scraper through B-1 and B-2 perfs. POOH. PU dry test assembly and RIH. RIH w/dry test BHA. Set RBP @ 11,437' DPM. Set PKR @ 11,325' DPM. Open Hydrospring. IF = 5" in bubble bucket dropped to 1/2" in 2 hrs. RO. POOH. IFP = 2554 psi. FFP = 2798 psi. Change rams. Test BOPE. RU and run production tbg. Running completion string. Fin running 4-1/2" tbg, SCSSV, set PKR @ 11,100'. Install tbg hanger. Land tbg. Set BPV. Thaw out BOP stack. N/D BOPE. N/U tree. Test to 5000 psi. Tested tree to 5000 psi. RU to skid. Released rig from Well D-1 @ 1200 hrs on 1/28/89. R/U floor, LD DP in mousehole. Fin LD DP. Prep to skid rig. FINAL REPORT. ,, Pipe Rams: ,Annular Closing Pres,~u.re Closing ~ime Op, ~.ng Ti~ ~ltnd Ram~ ~ Closing P~eSs~re ~, Closing Tim~ Gas ConS. com~tSst~ PI C Level R~cord~r _~. ~_. ....... ,, ~' , '" Drilling RaCe Redord~l ...... ~~"' " .... "'''~ STATE OF ALASKA " ALASKA OIL AND GAS CONSERVATION COM i~,_..0N 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 J~ Amend order [] Perforate [] Other E3 2. Name of Operator UNOCAL (Marathon Oil Company - Sub Operator) 3. Address P. O. Box 190247 Anchorage, AK 99519 4. Location of well at surface Leg A-2 Cond. #1 Do£1y Varden t'±atforn 755' FSL, 1,126' FWL, Sec. 6 - 8N- 13W- SM At top of productive interval 505' FSL, 3,243' FWL, Sec. 32- 9N - 13W- SM At effective depth 852' FSL, 3,586' FWL, Sec. 32- 9N- 13W- SM At total depth 885' FSL, 3,620' 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-1 8. Permit number 34-32 9. APl number 50-- 733-20068-01 10. Pool Hemlock 11. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length Structural Conductor Surface 2,527' Intermediate 9,690' Production Liner 9,569' Perforation depth: measured true vertical 12,071 ' feet Plugs (measured) None 9,772 ' feet 11,998' feet Junk (measured) 9,727 ' feet 32' of perf gun @ approx 11,865' Size Cemented Measured depth True Vertical depth 13-3/8" 2,100 sx 2,527' 2,419' 9-5/8" 2,066 sx 9,690' 7,929' 7" 820 sx 12,063' 9,776' See Attachment #1 ~bing(size, grade and measured depth) 4-1/2", 12.6#, N-80 Tb~ @ 9,455' MI); 3-1/2" 9.2# N-80 Tbg to 11,127' MD Packers and SSSV(type and measured depth) ' " 7" - 29# x 3-1/2" RH 1 Pkr @ 11,121' MD; 4-1/2" BV DK on Seal Loc @ 329' MD 12.Attachments 2,3,&4Description summary of proposal [] Detailed operations program..[] ~Q.P sketch [] 13. Estimated date for commencing operation August 1988 14. If proposal was verbally approved ~ubsequent Work Reportexi on Form No~ ......... ~-~ Dated.../_.ff.... Name of approver Date 15. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ~,~/~. ~'~/,~ .......... ~ ~¢. ~,-~ ~, Title Environmental Engineer R~)~(/D. Roberts Commission Use Only Date 7/6/88 Conditions 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 I Approval No. ~ '~--"~7 by order of the commission Date 7"'/..~' o°~7 feet Form 10-403 Rev 12-1-85 Submit in triplicate ~,/' Bench 1 2 3 4 5 6 Attachment #1 TBU Well D-1 Perforations 11,255' - 11,295' 11,320' - 11,410' 11,435' - 11,495' 11,515' - 11,670' 11,695' - 11,845' 11,865' - 11,925' TVD 9,163' - 9,194' 9,213' - 9,282' 9,301' - 9,347' 9,362' - 9,481' 9,500' - 9,613' 9,627' - 9,672' NEF/em/60/Sundr4 RECEIVED J~L - 8 1988 Alaska Oil & Gas Cons. Commission Anchorage Attachment # 2 Well D-1 Procedure 1. The tubing annulus will be filled with FIW prior to moving the rig over Well D-1. 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/6" bit and wash fill down to 32' of perf gun fish. POH. 6. RIH and retrieve fish. POH. 7. RIH w/6" bit and clean out to PBTD @ 11,998' MD. POH. 8. RIH w/bit and casing scraper to PBTD. Circ hole clean. POH. 9. RU WL and run csg. inspection log. 10. Pressure test liner lap. 11. Squeeze Hemlock Bench 2, excessive water production interval. 12. RIH and reperforate selected Hemlock intervals with TCP guns. POH. 13. RIH w/perm, packer and set @11,100' MD. 14. RIH w/redesigned gas lift system. 15. ND BOPE. NU and test X-mas tree. 16. 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. R [ £ £ IV £ D .J~ ~l. - 8 1988 Alaska Oil & Gas Cons. Commission Anchorage 4If' iqSO to "l]]U ~ D-I Completion Schematic (Current Completion) 4~" Ball Valve 329' 2" ID, Otis : 3,175' 4~" Otis US[ C2F Mandrels w/Guiderson H-77 vlvs 4.OY' ID .. .%9091 ,1 i, - , 6,9{3' " " . ,, 7,786' " - - 8,210' " - ,, 8,00~' tJ Ii It -. 8,902' " - ,, 9,193' " ,, ,, 3~" x 4~" X-~ver @ 9,455' 9,487'.3~" Otis USI C2F Mandrels 9,792'v/C~,,iders~fl,,M-7? vlvs 3.(XY' ID · 10,10l' " ,, ,, · {0,408' " - ,, · · {0,713' " ,, ,, 3~" ci~c sleeve {{,083' 2.75" ID -7" - 29~ X 3~" Ri[ pakcer {{,{2{' !~flearSub 11,127' 3" ID Perforations (DIL) Bench I ll,255' - 11,295' Bench 2 {{,320' - Bench 3 11,43§'.~.~ I,~§' ' Bench 4 l{,5{5' .- 1{,670' Bench 5 {1,695' - ll,845' · Bench 6 ll,865' - gge~ Fill @ }l.8lO' Il 925' in &oat32' i968 W~ 7/24/87 ~BTD @ 11,998' TBU Well D-I (Proposed Completion) Otis Ball Valve SSSV 3-1/2" Completion String 9569' - 12,063' 7" N-80 Liner 9690' 9-5/8" N-80 Csg 11,100' Perm Packer w/SBE Perforations (DILl B-1 11,255' - 11,295' B-2 11,320' - 11,410' (Cmt Squeezed) B-3 11,435' - B-4 11,515' - 11,670' B-5 11,695' - 11,845t B-6 11,865' - 11,925' 11,998'- PBTD 12,063' Bottom of 7" Liner 12,071' - 13) MARATHON OIL GO.-- DOLLY VARDE NI PLATFORM -- Attachment #4 U Drillin~ blipp)~- 0 ~ ~ 5,000 - Kill LinG, ,, -~ U [g gl~ , ~ ~CIW Swin~-Boito- Clamp ' I. --I / Connectors -- Di~r~~ 2 - 13~/S"x B, O00~ ~o o ! Riser ~ BOP Stack For io, , Drilling' From Uhd~r iB~/~" J I ~urf~ce O~sin8 To Z D-- '' .I In JIlL -8 ]988 Well Room Floor, 12"~,000~ O~sing Head w/Flgn~¢d 0utl~t~ ~ Valves I Collar 1'5 ~/~" Surf~c,e 33' C, onduofor "~S! STATE OF ALASKA t ALA ,,, OIL AND GAS CONSERVATION COM ,,~.. tN APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon ~ Suspend D Operation Shutdown ~ Re-enter suspended well ;-i Alter casing [] Time extension ~-- Change approved program ~- Plugging ~ Stimulate 2] Pull tubing ~:2 Amend order ~ Perforate ~.. Other 2. Name of Operator U~OCAL (Marathon Oil Company - Sub Operator) 3. Address P. O. Box 190247 Anchorage, AK 99519 ~- Location of well at surface Leg A-2 Cond. ~il Doily Varden k'iat~-ort~ 755' FSL, 1,126' FWL, Sec. 6- 8N- 13W- SM At top of productive ira, rval 505' FSL, 3,::~43' F~%, Sec. 32 - 9N - 13W- SM At effective depth 852' FSL, 3,586' FWL, Sec. 32 - 9N - 13W- SM At total depth 885' FSL, 3,620' F~rL, Sec. 32- 9N- 13W- SM 5. Datum elevation (DF or KB) ]06' KB above MSL 6. Unit or Property name Trading Bay Unit 7. Wel! number D-1 8. Permit number 34-32 9. APl number 50-- 733-20068-01 10. Pool Hemlock feet 11. Present well condition summary Total depth: measured true vertical 12,071 ' feet Plugs (measured) 9,772 ' feet 'Effective depth: measured 11,998' true vertical 9,727 ' feet Junk (measured) 32' of perf gun @ approx feet 11,865' Casing Length Structural Conductor Surface 2,527' Intermediate 9,690" Production Liner 9,569' Perforation depth: measured true vertical Tubing (size, grade and measured depth) Size Cemented Measured depth True Vertical depth 13-3/8" 2,100 sx 2,527' 2,419' 9-5/8" 2,066 sx 9,690' 7,929' 7" 820 sx 12,063' 9,776' REC. EIVED See Attachment #1 -8 ]988 ,0il .& Gas Cons. Commission 4-1/2"~ 12.6#, I{-,80 Tbg @. 9,455' MD; 3-1/2" 9.2# N-80 Tbg to 'l¢,"~0~geMD Packers ~;ad ~;SSV (type arm measures depth) ' 7" - 29# :: 3-1/2" tLH 1 Pkr @ 11:.121' 1~; 4-1/2" BV DK on Seal Loc @ 329' MD 12.Attachments 2,3,&4Description summary of proposal [] Detailed operations program Z BOP sketch [] 13. Estimated date for commencing operation August 1988 14. If proposal was verbally approved ~bnn No. . Dated Name of approver Date approved 15. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed 4~O:Z-,/'~./'~'~,£.~../.~ o.i~~ Title Environmental Engin eer Ro.C/D. Roberts Commission Use Only Date 7/6/88 Conditions of approval Notify commission so representative may witness Approval iqo. [] Plug integrity [] BOP Test [] Location c earanceI ORIGINAL SIGNED BY LONNIE C. SMITH Approved Copy Returned ¢-TM __ by order of Approved by Commissioner thecom~nission Date ~../2 ~ Form 10-403 Rev 12-1-85 Submit in triplicate Bench 1 2 3 4 5 6 Attachment #1 TBU Well D-1 Perforations 11,255' - 11,295' 11,320' - 11,410' 11,435' - 11,495' 11,515' - 11,670' 11,695' - 11,845' 11,865' - 11,925' TVD 9,163' - 9,194' 9,213' - 9,282' 9,301' - 9,347' 9,362' - 9,481' 9,500' - 9,613' 9,627' - 9,672' NEF/em/60/Sundr4 RECEIVED JIlL - 8 1988 Alaska ,Oil .& Gas Cons. Commission Anchorage Attachment # 2 Well D-1 Procedure 1. The tubing annulus will be filled with FIW prior to moving the rig over Well D-1. 2. Check to make sure well is dead. Set BPV. NU and test BOPE. Pull BPV. 3. Pull RH-] retrievable packer free and CBU. 4. POH and LD 4-1/2" x 3-1/2" completion string. 5. RIH w/6" bit and wash fill down to 32' of perf gun fish. POH. 6. RIH and retrieve fish. POH. 7. RIE w/6" bit and clean out to PBTD @ 11,998' MD. POH. 8. RIH w/bit and casing scraper to PBTD. Circ hole clean. POH. 9. RU WL and run csg. inspection log.. 10. Pressure test liner lap. 11. S~ueeze Hemlock Bench 2, excessive water production interval. 12. RIH and reperforate selected Hemlock intervals with TCP gun~. POH. 13. RIH w/perm, packer and set @11,100' MD. 14. RIH w/redesigned gas lift system. 15. ND BOPE. WU and test X-mas tree. 16. 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/60/Sundr4 .l~l,t - 8 1988 A~ska Oil & (~as Cons. Commission Anchorage _ t 4t/' ~ to ~' NSO* 9,569' - 12,063' > Completion Schematic (Current Completion) 4~" B~ll Valve 329' ~' ID, Otis IX 3,175' 6~" Otis USI C2F Handrels w/Guiderso~ H-77 vlvs 4.C~Y' ID 416~O' Il ,1 '1 6,913' " " ." 7,786' " " " 8,210' " " " 8,60~I ,, 11 ,, -. 8,902' " n , 9,193' n . . 3~" x 4If' X-over @ 9,455' 9,487'.3~" Otis USI C2F Mandrels w/guidersc~ M---77 viva 3.0(t' ID 9,792' " " ". · 10, I01' " " " · 10,408' " " ,, ... 10,713' " " " 31~" clrc sleeve 11,083' 2.75" ID 7" - 2°~ X 2~" ~lI pakcer 11,121~ !hear Sub 11,127' 3" ID Perforations (OIL) Bench I 11,255' - 11,295' Bench 2 11,320' - 11,410' Benek 3 11,435'.1~ 1,495' · Bench 4 11,515' .- 11,670' Bench 5 11,695' - 11,845' ~ench 6 II 865' - II 925' Tagged Fill~ 11.810' W[~l 'Gun loa£32 1968 I'BTD @ 11,998' ,. W~C ~-1-87 TBU Well O-I (Proposed Completion) Otis Ball Valve SSSV 3-1/2" Completion String 9569' - 12,O63' 7" N-80 Liner 9690' 9-5/8" N-80 Csg Il,tOO' Perm Packer v/SB£ Perforations (OIL} B-I 11,255' - 11,295' B-2 11,320' - 11,410' (Cmt Squeezed) B-3 11,435' - 11,495~ B-& 11,515' - 11,670' B-5 11,695' - 11,845' B-6 11,865' - 11,925' 11,99B'- PBTD 12,063' Bottom of 7" Liner 12,071' - TD - MARATHON OIL GO.- Attachment #4 L .___1~- Mud Pan )/ Flowlin~ D~iilin~ llippl~ -- DOLLY VARDEK! PLATFORM-- U O_,onduc±or . Well Room Floor ' [ £o' D~ill .... Deck Floor / - ~,~' z-,s'/~", s, oo0' ro '~ o, RECEIVED Ris¢r CBOP St~ck For to, , o j Drilling' From Uhdcr 13~/~" I I · JUL - 8 ]988 / , =J -- - 12'. 5,000~ O~sins: OutlEts ' i ] C°ll~r KI STATE OF ALASKA i?' ALAS , .)IL AND GAS CONSERVATION COMM'~._...,~ON REPORT OF SUNDRY WELL OPERATIONS i. Operations performed: Operation shutdown [] Stimulate [] Plugging [] Alter Casing [] 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 surface Leg A-2 Cond. #1 Dolly Varden Platfor~ 755' FSL, At top of productive 505' FSL, At effective depth 852' FSL, At total depth 885' FSL, 1,126' FWL, Sec. 6 - 8N - 13W - SM interval 3,243' FWL, Sec. 32 - 9N - 13W - SM 3,586' FWL, Sec. 32 - 9N - 13W - SM 3,620' FWL, Sec. 32 - 9N - 13W - SM 11. Present well condit Total depth: Effective depth: Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: ion summary measured 12,071' true vertical 9,772' measured 11,998 ' true vertical 9,727 ' Length feet Plugs (measured) feet feet Junk (measured) feet Perforate [] Pull tubing [] 5. Datum elevation (DF or KB) 106' KB above MSL 6. Unit or Property name Trading Bay Unit 7. Well number 8. Approval number 7-909 9. APl number 50-- 733-20068-01 10. Pool Hemlock None 32' of perf gun @ approx 11,865' Size Cemented MeasUred depth True Vertical depth 2,527' 13-3/8" 2,100 sx 2,527' 2,419' 9,690' 9-5/8" 2,066 sx 9,690' 7,929' 9,569' 7" 820 sx 12,063' 9,776' measured true vertical See Attachment #1 Tubing (size, grade and measured depth) gS~,2z.6#, N-80 Tb~z O 9~¢' 5' MD; 3-1/2", 9.2#, N-80 Tbg to 11,127' MD Pack (type and measdfecf d ' 7" - 29# x 3-1/2" R, 1 Pkr @ 11,121' MD; 4-1/2" BV DK on Seal 12. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure 13. 0il & Gas Cons. Prior to well operation Subsequent to operation Representative Daily Average Production or Injection Data 12/17/87 1/22/88 Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure ~bing Pressure 388 116 536 1160 psi 130 psi 47 247 1691 1280 psi 175 psi . 14. Attachment~: #2 Daily Report of Well OperatiOns [] 15. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed Robert~ Title Environmental Engineer Form 10-404 Rev. 12-1-85 Copies of Logs and Surveys Run [] Date 2/1/88 Submit in Duplicate Feet Bench 1 2 3 4 5 6 Attachment #1 TBU Well D-1 Perforations 11,255' - 11,295' 11,320' - 11,410' 11,435' - 11,495' 11,515' - 11,670' 11,695' - 11,845' 11,865' - 11,925' TVD 9,163' - 9,194' 9,213' - 9,282' 9,301' - 9,347' 9,362' - 9,481' 9,500' - 9,613' 9,627' - 9,672' NEF/em/60/Sundr3 Attachment #2 TBU Well D-1 Summary of Daily Well Operations 12/14/87 RU wireline. PT lubricator, RIH, latch, and pull ball valve. RIH w/2.625 gauge ring and cut scale from 11,083' to tbg tail. POOH. RU BHP inst and take FBHP survey. 12/15/87 Complete FBHP survey, return well to production. 12118187 RU wireline, PT lubricator. RIH w/30', 2-1/8" through tubing strip guns, 4 SPF, 0° phasing w/well shut in. Correlate and perf Bench 2 from 11,360' - 11,380' DIL. RIH w/30' guns as before. With well flowing, perf Bench 2 from 11,330' - 11,360' DIL. POOH, RD, put well on test. 12121187 RU wireline, PT lubricator. RIH w/30', 2-1/8" through tubing strip guns, 4 SPF, 0° phasing. Correlate and perf Bench 5 from 11,740' - 11,770' DIL. MU 30' guns as before, RIH, correlate and perf Bench 4 from 11,520' - 11,550' DIL. POOH. RD, put well back on production. NEF/em/60A/Sundr4 AL ,LA OIL AND GAS CONSERVATION CO ,,,,IIoSION 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 surface Leg A-2 Cond. #1 Dolly Varden k'iat2oru 755' FSL, 1,126' F~, Sec. 6 - 8N - 13W- SM At top of productive interval 505' FSL, 3,243' FWL, Sec. 32 - 9N - 13W- SM · At effective depth 852' FSL, 3,586' FWL, Sec. 32- 9N- 13W- SM At total depth 885' FSL, 3,620' 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-1 8. Permit number 34-32 9. APl number 50-- 733-20068-01 10. Pool Hemlock feet 11. Present well condition summary Total depth: measured true vertical 12,071' feet Plugs (measured) 9,772 ' feet None Effective depth: measured 11,998' feet Junk (measured) true vertical 9,727 ' feet 32' of perf gun @ approx 11,865' Casing Length Size Cemented Measured depth Structural True Vertical depth Conductor Surface 2,527' 13-3/8" 2,100 sx 2,527' Intermediate 9,690' 9-5/8" 2,066 sx 9,690' Production Liner 9,569' ~.~' .7" ~)~". z,:'~.~,, 820 sx 12,063' Perforation depth: measured _ true vertical f~,~' . # 1 Tubing (size, grade and measured depth) 4-1/2", 12.6#, N-80 Tb~ ~ 9,455' Packers and SSSV (type and measured depth) ' 7" - 29# x 3-1/2" RH 1 Pkr ~ 11,121' 2,419' 7,929' 9,776' AIaska Oil a,. C-'.a.s Cons.' 12.Attachment~: 2 Description summary of proposal [] Detailed operations program [] BOP sketch [] 13. Estimated date for commencing operation November 1987 14. If proposal was verbally approved Name of approver Date approved 15. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed /~¢2~~. ~~ Title Environmental Engineer ~oy O. Roberts c/j' Commission Use Only Date 11/20/87 Conditions of approval Notify commission so representative may witness I Approval No. ..---7 ~ [] Plug integrity [] BOP Test [] Location clearancel / '-~ ~" ~; Approved Copy Returned . ORI6INAL S,6NED BY ...... -1/'--~"".~? by order of Approved by LO,,IE C. SMF[H Commissioner the commission Date //-7.3J -~t Form 10-403 Rev 12-1-85 Submit in triplicate Bench 1 2 3 4 5 6 Attachment #1 TBU Well D-1 Perforations 11,255' - 11,295' 11,320' - 11,410' 11,435' - 11,495' 11,515' - 11,670' 11,695' - 11,845' 11,865' - 11,925' TVD 9,163' - 9,194' 9,213' - 9,282' 9,301' - 9,347' 9,362' - 9,481' 9,500' - 9,613' 9,627' - 9,672' NEF/em/60/Sundr3 Attachment 2 Well D-1 Procedure 1. RU Otis WL and PT to 2500 psi. 2. RIH and pull WLR AO Ball valve at 329'. 3. Make up dual Amerada bombs. 4. RIH and stabilize well. 5. Measure FBHP at 11,623' (9450' TVD). 6. POH and RD Otis. 7. RU E-line and PT to 2500 psi. 8. Perforate the following zones underbalanced or flowing and test as indicated. Ail runs will be with 2 1/8" through tubing strip guns, 4 SPF, 0° phasing. Run Interval (D IL) Feet Z one 1 11,360' - 11,390' 30 2 11,330' - 11,360' 30 Stabilize well and test 12 hours. 3 11,740' - 11,770' 30 4 11,520' - 11,550' 30 5 11,450' - 11,480' 30 6 11,260' - 11,290' 30 Tag bottom on last gun run B2 B2 B5 B4 B3 BI 9. RD E-line. 10. RU Otis and PT lub. to 2500 psi. 11. RIH with dual Amerada bombs and stabilize well. 12. Measure FBHP at 11,623' (9450' TVD). 13. POH and run WLR AOBV to 329'. 14. RD Otis. 15. Otis will read pressure charts, then send data and charts to Rose Hamlin in Anchorage. Data will also be sent to W. L. Browne in Nikiski. 16. Test well for at least 24 hours. NEF/60/Sundr3 Unocal Oil & Gas Divisi~r Unocal Corporation ~ P.O. Box 190247 Anchorage, Alaska 99519-0247 Telephone (907) 276-7600 UNOCAL DOCUMENT TRANSMITTAL Alaska District January 7, 1985 HAND DELIVERED TO: Bill Van Alen R.C. Warthen R. B. Stickney LOCATION: Anchorage LOCATION: Alaska District Alaska Oil & Gas Conservation Commission Transmitting: Data is included herewith for the following well: MARATHON TBU D-1 McArthur River Field Cook Inlet, AK Sec 32, TgN R13W ARI#507332008~00 Gyroscopic Survey: Schlum. (GCT) 0 to 4013' PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY OF THIS DOCUMENT TRANSMITTAL. THANK YOU. DATED: ~ummissio~ A~chorage SUB'SURFACE DIRECTIONAL SURVEY J-~'J Ul DANCE J-~'JONTINUOUS J-~-JooL RE.CE/VEl). JAN 0 7 1986 Naska U~ ~, ~ Uons. Commissiorl Anchorage Company Well Name FieldlLocation MARATHON OIL COMPA~Y TRADING,,~Y UNIT D-I' MCARTHUR RIVER~ KENAI~ ALA~K~ Job Reference No. 70632 Lo~3;ed By; HEATH Date 23-JULY-1985 Computed By: CUDNE¥ GCT DZPECTTONA[, SURVEY CU6TO~ER [,IST~'N~ ~ARAmHON 0~[,, C~MPANY TRA[)TN~ ~RAY UNT17 D-1 ~CARTHUR RIVER SJJPVEY DATE: 21-,]O~r-85 ~NCiNERR~ ~EAT:N g~.:THODS _nF CO~PUTATI.nN TOnG boCAT!ON: TA~G?N?I~h- averaged deviation and azimuth 1NTEPPObAT.T_ .O.~: LI ~,~EAR VF. RTICAL SgCT_TO~'; HARTZ, ~-IST, PROJECTE.n ONTO A TARGET AZIMUTH OF NORTH 10 DEC, 52 MIN MAST r~ADING Bay I1NIT qmA~T~U~ ~IVE K~N~I,AT, ASKA CONPUTA'rI~N DAT~; !0-JUL-85 DATE OF SU~V~¥t ~l-jUN-S5 KELLY BUSHING EbEV~T~ON~ 106,00 FT ENGXNEE~J HEATH INTERPOLATED VA[.UF$ FOR EVEN 100 FEET OF MEASURED DEPTH TPl]~ SUB-SEA COUPS~ ~EaSI!R~D VFRTICAL v~TTCAB D~VIATION AZIMUTH DEPT~ D~PTH DEPTH D~[; MIN D~G M~N 0,00 0,00 -106,00 0 0 ~ 0 0 E 1.00,00 100,00 -6,00 0 13 N 2~ 3a F ~00.00 200,0n 9~,o0 0 15 ~ 39 2~ E 300,00 299,99 193,99 0 17 ~ d3 2~ ~ ~ ',00 3~9,9~ 993,o9 0 20 ~ ~4 2 E .00 499 90 39; ~9 o 20 N 43 40 ~ -.~,00 5~9~99 493~9 0 2~ ~' ~¢ 31E 700.00 699 99 59a.g9 o 20 . ~4 2~ E ~00,00 799~9~ 69~,~8 1 g N 3 I g o00,o0 8o9,8~ 793.~5 4 27 ~ 4 33 ~ VERTTCaB DOGbEG RECTANGUbAR COORDINATES HORIZ, DEPARTURE SECTION SEVERITY NORTH/SOUTH E~ST/WEST DIST, AZIMUTH FEET DEG/100 FEET rEFT FEET DEG ~IN 0.00 0,00 0,00 N 0.00 -0.02 0,07 0,01 N 0,14 0,38 0,08 0,37 N 0,08 0.78 0,15 0,7~ N 0,40 !.26 0,0~ 1.13 N 0,79 ~,77 0.02 1,57 N 1,21 2,33 0,15 2,07 N 1.58 3,00 0,11 2,70 ~ 1,83 3.95 2,4J 3,62 N 2.09 ~,64 5.33 $,42 ~ 1,95 1~,95 1,9e 18,24 31,84 1,35 30,19 46,19 1,49 43,42 62,20 1,7] 58,01 80.33 2.03 74,32 lOJ,16 2,64 92,91 ~25,~3 2,06 114,27 ~52,51 5,46 ~38,89 ~?.~8 3,35 167.69 21.3.65 1,81 108,50 N 6 35 E 247,62 N 6 49 ~ 285,96 N 7 17 F 32~.64 ~! 'l lg V 374.79 ~ 7 24 ~ ~25.02 z 7 31. E 470.76 ~ 7 16 E 539,05 N 7 11E 602.36 ~ 7 1] ~ 667,45 ~ 7 4 E 739.56 tO00,nO 909.29 g9~,~9 7 g 1106,00 1098,]~ 092,~8 8 9 1200,00 11°7,24 1091.~4 9 ~ 1300.00 !205,'IR 1180.76 1.0 31 1400,00 ~3o3.7~ 1287,78 12 17 1500,00 ~.4ml 07 1]BK,~7 ~4 2~ lgO0 O0 15a'/;in 1481,]8 16 43 1700:O0 ~.6a2,87 1576.n7 17 32 1.~00,00 1778,13 1~7~,13 17 47 1~00,00 ~873,17 1767o~7 ~8 4& 2000.m0 !967,1~ 1861,18 21 15 2100 00 20S9,4~ 1053,48 23 5~ 22On:nO 2149'~6 2n43,~6 26 36 23On.nO 2238,52 2132.52 28 46 2~"0.00 2324.92 221R,92 11 44 2 O0 240S 53 2~02.~3 ~4 45 2..~..i:o0 24~8:95 2387,~5 38 ~ 2700,00 2566,24 246n.74 40 19 2~00.00 7642.05 2536.05 40 53 2900.n0 27~7.83- 2611,~3 aO 35 ~000,00 2703.37 2687,37 41 31()0.o0 2868,61 2762.61 al 5 3200,n0 2943,57 2837,57 41 46 3300.00 30!8,05 2q12,n5 41 52 ]400.00 3092.06 2°86,06 a2 49 350n.n0 3164,91 3n5~,91 43 25 1600,~0 32~7.46 3131,46 43 36 3700.00 ~309.7~ 3203,71 43 49 ~O0.nO 33~1.6] 3275,~3 44 13 tgOn. O0 3453.27 3347,27 a4 16 N 6 50 F 797.~4 ~I 6 37 E 863,65 ~ 6 32 ? 920,65 '~ 6 49 E 996,18 ~ 11 1~ F 1063.37 ~ 11 27 ~ 1131.~6 ~ ll 22 ~ 1200,68 N 11 7 ~ 1269,~1 ~ I0 5l E 1409,06 0,00 a 0 0 E 0,14 N 86 4 W 0,39 N 12 ?0 g 0.8~ N 29 lb E 1,38 N 34 56 E 1,9~ N 37 46 E 2,60 N 37 23 E 3,26 N 34 6 E 4,18 N 30 4 E 8,64 N 13 4 E 5,47 E 19 05 N 16 41 g 11,64 E 32:35 N 21 4 E 18,86 ~ 47.3a N 23 28 E 27,70 ~ 64,29 h 25 31E 38.9t ~ 83,80 N 27 38 g 52,6~ E 106,77 N 29 31 E 68,97 ~ 133.47 N 31 6 E 65,43 ~ 163,06 N 31 35 E 94.93 E 192,69 N 29 30 E 99,25 ~ 221,93 N 26 33 E 3.01 3,02 1.67 2,70 3,20 3,49 2,83 1.13 232 34 N 103,11 ~ 254,19 N 23 55 E 270:5~ N 107,60 ~ 291,13 N 2I 41 g 3~2,97 N 1~2,89 E 332,7~ N 19 50 ~ 358.83 N 1~8 77 ~ 377,97 N 18 18 E 408'75 N 125:19 ~ 4~7,49 N 17 I E 463 Il g 132.31 ~ 481,64 N 15 56 E 522:0~ ~! 139.98 ~ 540,46 N 15 0 E 584 97 N 147,91 ~ 603,38 N 14 11 E 649:67 g 156,08 ~ 668,16 N 13 30 E 714,42 ~! 1~4,16 ~ 733,0~ N 12 56 E 0,87 0,50 1,3~ 1,37 0,18 0,35 0,60 O,4R 79,41 ~! 172,33 g 798,25 N 12 28 E _44,84 N 180,13 E 863,8~ N 12 2 E 910,58 g 1~7,76 ~ 999,73 iq 11 39 E 976,8~ ~ lO5,27 E 996,21 N 11 18 E 1043.29 N 205.72 ~ 1063,38 N 11 9 E 111.0.41 g 219,37 ~ 1131,8~ N 11 10 E li77 89 ~ 232,93 E 1200,70 a 11 11E 1245~6~ ff 246,50 ~ 1269 83 N 11 11 E ~313 89 ~ 259,7! ~ 1339~3~ N 11 10 E 13~2~38 ~ 272,98 E !409,08 a 11 10 E PA~£ 2 ENGTN~ER: HEATH I~'£E~{PO[,AWEO VA!.UES FOR EVEN lO0 WE~ OF MEASURED DEPTH TP[)~ SUn-SE~ COUPS~ VERTICAL DO~LEG RECTANGULAR COOrDINATeS HORIZ. DEPARTURE "FiAS[!R~O V~RTI~A[, VE~T~CAL D~VTATION AZIMUTH S~CTION S~VERI?Y NORTH/SOUTH E~ST/WEST DIST. AZIMUT~ 4000.00 ]5~5.0n 341~,09 44 17 M 10 55 ~ 147~.R5 1,6g 1450,75 M 2~6,00 E ~478,67 N 1! 9 E ~0~.~0 ~514.~ 342~.]8 4~ 16 M lO 52 E 1487,74 0,00 ~459,67 M 2~7,72-M ~4~7,75 N 1! 9 g TRADI~!G B~¥ U~IT COMPUTATION O~: lO-JUL-RS PAGE 3 DATE O? SURVEYt 21-dUN-85 KELDY BUSHTNG EDEVATIONI 106,00 INTERPOI,ATED vAr,uEs FOR EVEN 1000 F~ET OF M~ASUREO DE~T VERTICAL DOGLEG RECTANGUbRR COORDINATES HORTZ, DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST, AZTMU~M FEET DEC/lO0 FEET FEET FEET DEG ~IN ~ ~5 29 ~ 1~.95 N b 35 ~ 247.62 ~ 6 59 ~ 797.94 N 10 55 ~ 147~.65 N ~0 59 E 1~87.74 0,00 1,98 3,01 0,87 1,69 0,00 0.00 N 0.00 E 0,00 N- 0 0 E 18 24 ~ . 5,47 ? 19,05 N 16 41E 232 34 N !03 1t E 254,19 N 23 55 E 779 43 N 172,33 E 798,25 N 12 28 E 1450 75 N 2~6,00 E 1478.67 N 11 9 E 1459 67 N 287,7~ E !487.75 Nll 9 E MAR.AThOS.! OIr, CO~_PfiN¥ r~ADI~'G t3l't UNIT COMPU?ATIt)N DATE: IO-JUI.-R. 5 PAG~ 4 DATE OF SURVEil 21-dUN-aB KELh¥ BUSHING EbEV~TION: 106,00 FT ENGTN~E~: H~A?~ iNT~iRDO[.A'~ED VALUES FOR EVEN 1(30 FEET OF SIjR-SEA n. EPTN '-~E~-S~R,'RO V;'RTIrAL VE~TIChb DEVTATION AZi~UTH O.mO 0.0~ -106.00 0 6.nO 6.00 -fOrt.nO 0 29 N 49 2~ W 10~.00 1o6 00 n.00 o 13 ~06.n0 206100 !00.0o o 15 306.01 306,00 900.00 0 17 "~6.nl 406,00 t00,00 0 20 5.01 506,00 400.00 0 20 '.~6,nl 60~.00 500.00 0 25 706,01 706,00 600.00 0 21 a06.~2 8n6.0a 700,00 VEPTICAL DO~b~G RECTANGULAR COORDINATES NOR?Z,. DEPARTURE SECTION SEVERITY NORYH/SOUTH ~AST/WEST DIST. ~ZIMI.ITH FReT PEG/100 FE~T FEET FEET DEG O.00 0,00 0.00 ~! 0,00 0,00 0,00 0,00 ~ 0,00 0.01 0,05 0,03 N 0,13 0.40 0,O9 0 39 N 0,10 0. 0 0.13 0:74 0.4 1,,~9 0.04 1,15 N 0.8t 1.80 0,0~ 1,59 N 1,24 2.37 0,10 2,11 N 1,60 3,03 O,lO 2,73 ~ 1,84 4,07 2,7B 3,74 N 2,10 o06,16 9o6.00 ~00.00 4 41 1006,76 1006,0o qOO.O0 7 !6 1107.70 1106 O0 1000.0() @ 14 170~.~8 1206~0o 110~.00 9 1~ lllO.al 1306,0o 1200,00 10 4~ 1417,51 ~406.00 1~0o,00 12 32 !~15.~2 !506.00 1400.n0 14 46 161q,46 !6~6,00 150fi.nO !7 n 1724 ~b !706,00 1~()o o0 17 39 1~20~7 1.8n6.00 1700:~0 !7 55 1034 75 1906 On IRO0,O0 19 29 2041'n3 ~On6:on 1~oo.o0 22 25 2151:19 71o6.0o 2nOO.oO 25 23 2~63.06 2206.00 2100,00 27 ~9 2377.94 23o6.00 2900.00 ]1 4 2~o&.~3 2406,00 2~0n. O0 34 3~ 2: .73 250§,00 2400.00 ~8 3~ 2~,,~.'2 34 2606,0n 2500,00 40 45 2R84[43 ~706,00 2600.00 40 32 3n16,77 2806,00, 27on.00 al o O.ll 6.98 8,89 lO.76 1.74 19,01 32.~9 1,36 .31.16 47.54 1.21 04,65 63.97 2,03 59'62 82,77 2,00 76'5! 104,65 2,40 96.0! 13n.29 -1,45 118,77 159.65 4,62 145,57 !91.K4 1,76 176.5-2 ~' 6 27 E 225.01 ~ b 4! ~ 263,15 N 7 6 E 307.27 u 7 19 E 357,31 M 7 21 ~ 413,50 N 7 31 E N 7 o E 552.~0 ~ 7 7 ~ 636.]4 u 7 ~ ~ 72~.45 ~ 6 54 E ROb,Ob 3149 71. 2906 oo 2~0o.0o 41 2~ 3783:~2 30o6~00 2~00.00 4t 51 3410.04 3106,00 3n00.00 43 1 3q56.~9 3206.00 3!00,O0 43 2~ 3694.n5 ~306.0n 3~00,00 03 4~ 3~34.n3 3406,00 3300.00 44 15 397].42 3b06,00 ~40~,00 43 55 401~.n0 ~534.3fl 342~,~$ 44 16 ~ 6 43 E fl96.31 ~ 6 33 E 085.42 N 11 2~ ~ 1076.33 u 11 19 E 1170,78 ~ ~1 g E 1266,24 ~ !0 59 E 1363.04 ~ ~0 47 E 1460.1b N ~0 5~ ~ 1487.74 2,44 2,61 2,7~ 2.54 2,91 3,42 2,77 0,56 0,47 0.5~ 0.91 1.14 0,11 0,64 0.34 1,1~ 0,00 1,99 5,83 12.15 I9,57 0,00 N 0 0 E 0,00 N 90 0 E 0.13 N 7~ 11 ~ 0,40 N 14 5 E 0.85 N 29 46 E 1,4! N 35 10 E 2.02 N 37 52 g 2,65 N 37 9 E 3,30 N 34 0 E 4,29 N 2g ~9 E 9.11 N 12 ]5 g 9i 88 N 17 3 E 33 45 N 21 1.8 g 48,75 N 23 40 E 28,76 E 66,19 N 25 45 E 40,48 E 86,56 N 27 52 E 54,97 E 110,63 N 20 47 E 72,40 E 139,10 a 31 22 E 88.43 E 170 34 N 31 !6 g 96,41E 201~13 N 29 38 E 209,81 N 100,53 E 232,65 h 25 36 £ 247,81 N I04,90 E 269,10 N 2~ 56 g 2ql,73 N ll0,1q E 311,84 N 20 41E 341,45 N 116,55 E ]60.80 N 1~ 50 E 397,30 N 123,7! E 416,11 N 17 17 E 461,38 N 132,0~ E 479,92 N 15 58 g 535,3q N 141.b7 ~ 553.82 h 14 49 E 618,74 g 152 17 -~ 6~7,1~ N 13 ~9 E 704,37 ~ 162:91E 7~2,96 N 13 1E 790,38 g 173,67 E 809,23 N 17 ~3 £ 877,37 N 183.88 E 896,43 N 1! 50 E 966,17 N 104,02 E 9~5.45 N 11 21 E 1056,00 ~ 208,29 E 1076,35 N 11 9 E 1148,57 N 2~7.05 E 1.170,80 a 11 10 E 12t2,1~ N 245,81E 1266 26 N 11 11 E 1337.21 N 264,24 E 1363~06 N 11 10 E I4t2.58 g 282 5~ E 1460,1~ N ll 9 E 1459.67 g 287~7~ E 1487,75 N I1 9 E TPA~I~!G 8AY U~I· K~N~I,A~..A~K~ T.r) COMPUTATION IN'~R~O[.ATED VALUES FOR CHOSEM HOP-,IZOMS PAGE 5 OATE O~ SU~VE¥~ 21-dUN-85 KELLY BUSHING ELEV~TION~ 106.00 FT EMGTNEE~ HEA?H DEPTH 40~_3.00 SURFACE [,OCATZON AT ORIGIN= SEC 6,TSM,~13W TVD RECTAMGUBAR COORDINATES F~O~ KB SUB-SE~ MORTN/SOUTH E~ST/W£$T 3~34.38 3428,38 145~,67 N 287,72 E ~ a R A'I'{.;O W OIL T~AI")J. NG Bay U',;I"T' n-.'l K~Ii A ~, ~T,,ASK A MA~K~R TD ************ SVRATTGPAPH~C MEASUPCD ngPTN dO13,00 lO-JUL-89 PAGE 6 DATE OF SURVEY: 21-dUN-85 KgLLY BUSHTNG ~bEVA~ION: 106,00 ENGINeEr: HBATH $!!NMAPY FRO~ KB SURFACE LOCATION AT ORTG)N: SEC 6,TSN,R13W TVD RwCTANG!JLAR COORDINATES SUB-SEA NORTH/SOUTH EAST/W£ST 3534.38 3428,38 1459,67 N 287,72 E ~T SLIB-$EA VEDTTC~[, n~;PTH HORTZONTA[, 1487.75 SCHLUMBEROER D I RECT I ONtqL SURVEY COMPANY MARATHON OIL COMPANY WELL TBU D- 1 FIELD MCARTHUR RIVER COUNTRY USA RUN ONE DATE LOOOEO 2i-JUN-BS REFERENCE 000070632 ISO. 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L..;..&.,,;,,..;,,.; ..... "'t'"r"t'"r"T"'?""~ ....... ~ ........ r"r"r"r"T'"r"r-~ ........... ?"~ ....... r"F't ................... +"T'"? ...... f'"'P'r"?' r'"f"T"f'"'h'T ........ ?'"rT"r'"r"r"r"t ........ r";'"?'T':'"'r':"";"','"'r'?'"'r'~ ...... ?r'"r't ........ ~ ......... '"?f'"+'"'~Th'"'"7'"f ............. ~'"+ ........ ] ................. ~ ........ ~ ........ ~ ....... f"f'"'?"f ........... ~'"+"?"f"'P'~ ........ +'"; .............. ~'-'?T"F'7'~'"'~'"I ............. h"~"t .... ~ ........ ?'1 ........... I 'f ............... ; ...... ] ................ -lSO0 -lO00 -SOO 0 500 lO00 ISO0 2OOO EAST ALASKA ,g AND GAS CONSERVATION C MISSION SUNDRY NOTICES AND REPORTS ON WELLS OTHER 1. DRILLING WELL [] COMPLETED WELL 2. Name of Operator 7. Permit No. Union Oil Company of California* 67-80 3. Address P.O. Box 6247, Anchorage, Alaska 99502 4. Location of Well Surface: Leg A-2, Cond #1, Dolly Varden Platform 755.3' FSL, 1125.5' FWL, Sec 6-8N-13W-SM 5. Elevation in feet (indicate KB, DF, etc.) KB 106.2' above MSL 6. Lease Designation and Serial No. ADL 17594 8. APl Number 50- 733-20086 9. Unit or Lease Name Trading Bay Unit 10. Well Number 11, Field and Pool McArthur River Yield 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). It is proposed to reperforate Hemlock Benches 1, 2, and 4 with 4 HPF as follows: Bench 4 11,515''11,560' DIL 11,575'-11,605' DIL 11,610'-11,670' DIL **Bench 1 11,252'-11,280' DIL **Bench 2 11,320'-11,406' DIL Subseqnent Work Reportecl *Marathon Oil Company - Sub-Operator RECEIVED APR 0 ! 1982 Alaska Oil & Gas Cons. Commission Anchorage **Bench 1 will only be reperforated if the increase from Bench 4 is insufficient. Bench 2 will only be reperforated if the increase from Benches 1 & 4 are insufficient. 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed Title DTRrP The spade below for Commission use Date 3/3]/R2 Conditions of Approval, if any: Approved by . . ORIG~IAt SIt, NET} BY LOH~IE C. SIV]lTtl COMMISSIONER Approved ,-opy Refurned By Order of the Commission Form 10-403 Rev, 7-1-80 Submit "lr~tentions" io Triplicate and "Subsequent Reports" in Duplicate -"':" STATE OF ALASKA ,,..' ALASKX' ,,_ AND GAS CONSERVATION &,v,,vllSSlON SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL:3~ OTHER [] 2. Name of Operator 7. Permit No. Union Oil Company of California* 67-80 3. Address 8. APl Number P. O. Box 6247, Anchorage AK 99502 50-733-20086 4. Location of Well Surface: Leg A-2, Cond #1, Dolly Varden Platform 755.3' FSL, 1125.5' FWL, Sec 6-8N-13W-SM I 6. Lease Designation and Serial No. ADL 17594 A-887 5. Elevation in feet (indicate KB, DF, etc.) KB 106.2' above MSL 9. Unit or Lease Name Trading Bay Unit 10. Well Number ])-1 11. Field and Pool McArthur River Field Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations Z Altering Casing [] Stimulate [] Abandon [] Stimulation [] Abandonment [] Repair Well [] Change Plans [] Repairs Made [] Other [] Pull Tubing [] Other [] Pulling Tubing [] 12. (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). On 9/10 - 9/11/81 Bench 5 was reperforated under drawdown at the following intervals using a '2-1/8" enerjet gun set at 4 HPF: Bench #5 11,695'-11,770' 11,806'-11,836' Benches 1, 2, and 4 were not reperforated, as requested in Sundry Notice, Intention of, dated 9/14/81. It was decided that at this time it would not be beneficial. Production prior to Reperforation: 1275 BFPD, 42% BS&W, 740 BOPD Production after Reperforation: 4858 BFPD, 65.75% BS&W, 1664 BOPD~t~V~U *Marathon Oil Company - Sub-Operator OCT ? ~ lq'?1 0it & Gas Cons, Commission Ancho'rac~e 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. SignedT/~/ ~. ~,~2//.~/~ Title D.]~'[ D~L'G SUPT The space b~10w for'C'ommission use ' --/ - Date 10/16/81 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 STATE OF ALASKA ~(" ALASKA OIL AND GAS CONSERVATION COMMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELLX3 OTHER [] 2. Name of Operator Union Oil Company of California* 3. Address P.O. Box 6247, Anchorage, AK 99502 4. Location of Well Leg A-2, Cond #1 Dolly Varden Platform 755.3' FSL, 1125.5' FWL, Sec 6-SN-13W-SM 5. Elevation in feet (indicate KB, DF, etc.) KB 106.2 Above MSL 12. I 6. Lease Designation and Serial No. ADL 17594 A 887 7. Permit No. 67-80 8. APl Number 5o- 733-20086 9. Unit or Lease Name Trading Bay Unit 10. Well Number :D-1 11. Field and Pool McArthur River Field Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate ~ Alter Casing [] Perforations [] Altering Casing [] Stimulate [] Abandon [] Stimulation [] Abandonment [] Repair Well [] Change Plans [] Repairs Made [] Other [] Pull Tubing [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). It is proposed to reperforate Hemlock Benches 1, 4, 5. If needed, Bench 2 will also be reperforated. Bench 5: 11,695'-11,770' 4 HPF 11,806'-11,836' 4 HPF Bench 4: li,515'-11,560' 4 HPF 11,575'-11,605' 4 HPF 11,610'-11,670' 4 H?F Bench 1: 11,252'-11,280' 4 HPF ' 11,290'-11,300' 4 HPF ' . Bench 2: 11,320'-11,406', 4 HPF Verval approval was received from Jim Trimble to Tony Swan on September * Marathon Oil Company Sub-Operator Signed Title DIST DRLG SUPT The s_~~below for Commission use Cond~ons ;7 ~;7 ~ Date. 9/14/81 Approved by. Ap.pcoved C~p'~ COMMISSIONER the Commission Date Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate Marathon Oil Company RECEIVED NOV ? 1 t77 Division of Anoh~r'~O Mr. 0. K. Gilbreth State of Alaska Division of Oil and Gas Conservation 3001 Porcupine Drive Anchorage, AK 99501 Anchorag ion Productiofl ,..,perations, U.S. & Canada P.O. Box 2380 Anchorage, Alaska 99510 Telephone 907/274-1511 November 15, 1977 We received Your letter to Mr. A. Mechler, Jr., dated November 2, 1977, in which you mention that Marathon failed to keep the State adequately informed as to the progress made in correcting deficiencies found during an inspection of the Dolly Varden Platform on September 28. Marathon respectfully apologizes for this oversight. As .you may recall, the inspector found the following deficiencies: .... · ,~ . ...:.:~,.... ~.....,,~.~ ~.:.:,... Well D-1 '.,~.,.:i'~ Downhole safety valve unseated and blew up ...... ~':,' ...................... ,,,,, ............... .......... into wellhead; Well D-10 Downhole safety valve would not test; Well D-29 Surface shut-in control did not work. The defective 'ball valve in Well D-l'was replaced on September 29. A reconditioned USI manumatic surface safety valve was installed on Well D-29 on October 1. The problem with D-10 was not as easily corrected. The defective safety valve in Well D-10 was an Otis tubing retrievable valve. Our personnel and representatives from Otis Engineering worked with this valve., off and on, for about a week attempting to get it to hold pressure. This included "stroking" the valve and dumping a polishing com- pound on the ball of the valve and then opening and closing the valve in an attempt to "seat" the ball. This ope.ration failed. It was then decided to lock the tubing retrievable ball valve out of service and install a wireline retrievable valve. .Two wireline retrievable ball valves were tried Mr. O. K. Gilbreth - 2 - November 15, 1977 before we were successful in getting one to hold. The second valve installed was a "soft-seated" valve and had to be ordered from Houston, Texas. Delivery of this valve took about a week. Mr. Russ Douglas witnessed the testing of this valve on November 10, 1977. Again, Mr. Gilbreth, we would like to apologize for our failure to keep you informed of our progress in this matter.~ however, we would like to assure you that we share your concern and were working diligently to correct the situation. You will be kept fully informed on such matters as these in the future. CAD:i CURTIS A. DOWDEN Operations Superintendent l~maa~0er 2, 19~77 A. Mechler Jr. Div. Oper. Z~4]r./ P. O. B~ 2380 99510 ~ an inspect/om trip, to your Dolly Varden platfon~ cm September 28, 1977 .problems, ~ found 'with ~lls as follows: Problem Do~le Safety 'valve Surfaoe shut-in cc~I did not w~rk. 0~ ~ ,21, 1977 your opera~ called our offic~ to report that the prob~ with wells D-1 and D-29 had be~ ~ctmd ~ that 'well D-10 On N~ ,:2, 1977' our in~ called your operator s~ we ~ not reoei~md a ~1 reg~ wmi1..D-10. Our inspector was inf~ that the ,~e safety valve, in ,well D-10 ~ ~ been replao~ because you ~re short a lubricator. Over ~ w~aks ~passed ~fc~e we ~v~d ~ord that the problems wells D-I and D-29 had been corrected. We ,feel ~zis, is ~ than reasonably neces~ to correct ~, type of problems. Hc~=ve~, it has been five weeks for %~11 D-10 ar~ it still ,has not been f~. 2 N~ 2, 1977 We will be sending an inspector to your platform ~ Wednesday, November 9 ~ 1977. If ~he probl~ with ~ D-10 has not been oorrected, ~ will c~nsi~ that it is in violatic~ of our recj'u~:at~cr~ and will :eocel~d ~iate O. K. Gilbreth, Jr. D~ 8/20/69 WELL NO. STATE D-1 LEASE Alaska :' rToP OF OIL STRING _ MEASURE;.:ENTSI{~TOP OF ROTAR~ TADLE~ TAKEN FRO.~ 1 {ORD. or MAT HIS¥ORY OF OIL OR GAS BLOCK TBU SEC. 6 PARISH' Kenai Borough 'cOUNTY KB E~Ev. 117' MLLW' 74.45'" . ELEV. __ ELEV. ll6' " H~tSTORY PREPARED BY. TITLE ELEV. FIELD McArthur Riv. er_ HLB-~ - - . TRM -V-'/ - .OKG ~ rTWPo ~'~/~" ~"( ~3W REL Oohn R. ~a~ber Production Superintendent It is of the ereotest importance Ia hove o complete history of lhe well Use lhis form in reporting lhe history of all imporlonl operations el lhe well, together wi~h the do;cs Ihereof, including size of hole, s;ze and numr.,er of bils, complele description of casing, cementing, fishing or drilling d;fficuhies, surveys, aH lests, ali completion op. erotions and procedure, etc. DATE 1/24/69 .. ~/25 - . - o 6/30 7/1 7/2 7/3 7/4 Moved rig from Well D-3 to Well D-1. Rigged up Otis wireline and lubricator on · long string. .- : . -.- .. - .']'F '~-" ' ' il Rigged up lubricator,,, on long string, and tested to 4000#,.OK. Pulled 3-1/2 ball valve. Ran in hole with 3-1/2" shifting tool, and opened all 3-1/2" gas lift. mandrels, with the exception of valve Ho. 13. Set and tested 3-1/2" ball valve,'0K. Rigged down lubricator and Otis wireline unit, and turned well to well clean tank. Released rig at 1400 1/25/69. Flowing well to v/ell Clean tank. . . · PB 11,998' ' ~- ~ . · -. ;- . Mo'ved rig from D-I'9 to D-I. 'Rigged up Otis wireline. Ran pulling .tool in long string' to pull .ball valve, pulled ball valve free. Started out of hole with wireline and valve, ball valve hung up 50 feel from 0, or 8 ft under Xmas. tree. Started'pumping mud down long string and up short string to kill well. Had 140 Nq. · bbls pumped at 7 Released rig on D-19 at 7 AM. Moved tO D-1 6/30/69 Loading tubing string with mud. '. ..~ .- . · PB 11,998' :- . - - . " · ~ ., ~ontinued pumping invermul mud down long string and up short string.· Pumped-a tot21 of 310 bbls, but did not get returns. Shut pump do~'./n and long string pressure went to zero. Pulled Otis wireline and found it had pulled out of ~ope socket, leaving ball valve and retrieving tool in hole. 'Ran overshot and latched onto fish which ~/as stuck in tree. Jarred fish loose and pulled it out. Ran in hole. with Otis XX plug and attempted to set it in X-nipple at 11,164'. Tripped jars and'pulled out of hole and found plug still on setting tool.' Laid down plug and continued circulating. Got returns with 372 bbls. Ran-shifting tool and opened c~rculating sleeve at 9502' and started displacing annulus with mud. Pumped and additional 270 bbls of mud. Switched displacement from p~oduction header to mud tank when return fluid weighed 8#/gal. Used a total of 642 bbls of-mud? Started circulating mud thru mud tank to knock out air and gas pockets when' dis¢l~arge line into mud tank began surging and gas got stronger. Shut well in and tubing pressure held at 300 psig. . PB 11,998' " - · Mixed 367·sx barite to protecto-mul mud to raise weight from' 3# per gal to 8.8#)gal. CirCulated mud around to degas. Otis ran dummy valve in long string. Pulled ball 'valve in short string and ran dummy valve in :short string. Cameron i.nstalled back pressure'valves in both strings. Dismantled and removed dual tree. Installed riser and BOP equipment. Nippled up. PB 11,998' : Finished nippling up, 'Rigged up dual string slips'and elevators, Star~ed laying down 3-1/2" tubing at.2 PM, Laid down du~l tubing string, PB 11,998' Completed laying down dual 3-1/2" tubing s~:rings at 7 PM. Picked up for state burn mill and packer picker, and 3-1/2" and 5" drill pipe. Went in hole with mill and packer picker. _ \ DATi~ WELL NO. D-1 LEASE STATE rl~r_ HISWRY OF OIL OR GAS ~.~LL BLOCK SEC. PARISH COUNTY FIELD T~¥P. ELEV. __ rTop OF OIL STRING MEASURE~ENTS / TAKEN FRet,! iTOP OF' ROTAR~ TA-3LE GRD. Of~ ELEV. E ~-- EV .... ELEV. H~ISTORY PREP/~REO BY L TITLE it is of fha greatest impatience to have a complele hislory of lhe well· Use this form in reporting the history of oil imporlant operot;ons et lhe well, together wilh :he dates lhereof, including size of hole, size and number of bits, complele description of casing, cementing, fishing or drilling difficuhias, surveys, ~11 tests, all completion operations end Procedure, etc. DATE 7/5/69 7/6 . . . . .. 7/7 7/8 7/9 7/10 : .. PB 11,998' ' ' ' "' '- "- ' ': - ' _ -. . . Finished in hole with Tri-state burn mill and packer picker. Tagged top of -. packer at 11,148'. Hilled on same for 6 hrs. Pulled out of hole. Did not recover packer. Bottom of mill worn slightly with no marks on inside of tool to indicate fish coverage. Went back in hole with 6" OD mill and 3-3/4" x 3-1/2" packer retrieving tool. Went in hole. with Mill #2. -, . . . .. PB ll ,998' Finished going in 'hole with 6" OD mill and 3-3/4" packer picker. Tagged top of packer at 11,148'. Milled on packer for 4 hrs and packer 'broke loose ,P, ulled out of hole, r~covering packer and tail pipe assembly. Went in hol-e-wit~ 6 bit and Baker casing scraper. Found fill at 11,620' (378' of fill up) rotated and washed down to'PBTD. Started out of hole with bit and scraper. - . PB 11,998' ' -' : -. ' : . - F;.inished out of hole with 6" bit and Baker scraper. ' Rigged up Lane Wells unit' and tested lubricator to 2500 psi - OK. Perforated the following'intervals w. ith 4" cc/ne shot casing gun 4 holes per ft, 11,262-11,292', 11,320-11,410, 11,460- 11,490', ll 5,15-}1.,665, 11,695-11,845', 11,870-11,930'. Ran gauge ring and JUnk basket to li 250 Rigged down perforating unit. Rigged up to run tubing.. · . .. " PB 11,998' .. Finished rigging up to run tubing. Ran in-hole with Guiberson 7" x..3--1/2" RH-1 packer, circulating sleeve, gas lift valves and Otis ball valve nipple on 59 jts 3-1/2" SL and 292 jts 4'1/2" SL tubing. Landed tubing hanger in tree with top of packer at 11,119,45' and bottom of seating sub at 11,126 35'. Installed back p~essure valve. Removed BOP's and installed Xmas tree. T~sted Xmas tree to 5000 psi - OK. Rigged to displace mud with d~esel oil. . · PB 11,998' ' · · Di~splaced hole with 750 bbls diesel oil.' Dropped 1-1/2" brass bail and set Hyd packer. Did not have surface indication that packer set. Pressured up to 4200- psi with no-bleed off. Rigged up Otis and tested lubricator to 2500 psi, OK. .Pulled dummy valve and ran 1-7/8" sinker bars to ll,200', approximately 75' below packer. Pulled out of'hole. Ran in hole with 4-1/2" ball valve and set same. Rigged down Otis.. Started moving rig.. Rig released at 8 PM 7/9/69. · · PB 11,998' Started gas lifting well to unload diesel oil at 1:.30 AM 7/10/69. The top valves unloaded and thiefed gas. Shut in well D-17 to use additional lift gas and raise pressure on D-l'to 1340 psi. Unloaded diesel and started getting formation oil at 8 PM. Put well on test at 8 PM. Eleven hour test. The well ~roduced 3728-B0, 7 BW and 1828 HCF of gas. Gas injected for lift was 1018 [,iCF. Oil gravity measured at 32.2°API, BS&W cut.O.2 of 1%. Based on 24 hours the well capacity is calculated at 8133 BOPD, 3988 HCF/D, 16 BI,IPD, using 2220 MCF/D of lift gas. The produci'ng ga~ oil. ratio is 217 cu. ft.-per bbl. The lifting ratio is 273 cu. ft per bbl. Producing tubing pressure is 120 psig, and the casing pressure is 1160 psig. The choke is open. Continuing to flowTwe~t,.1~for further stabilization. - · · _ -' - -. _ _ D_IVISION OF DATE o PAGF '~ . HI$~'~ORY OF'' OIL. OR GAS ~EL.L FIELD WELL NO. D-I STATE .LEASE bLOCK SEC. PARISH COUNTY ELEV. __ ELEV. __ ~ ELEV. EIEV. ToP OF OIL STRING H. ISTORY PREPAREI3 BY · MEASUREMENTS I ~' '- TITLE ToP OF ROTARY TABLE TaKr- N FRO,~ [GRD. OR N~,AT TWP. R. II is of lhe greatest importance to hove o complete hislory of the well. Use this form in reporling Ihe hislory oF oil importonl operofion? al the we!l, together with the doles :hereof, including size of ho!e, size and numl~er of bits, comptele description of casing, cementing, fishing or drilling dlfficuhies, surveys, all res:s, oil complelion operoticms end procedure, etc. DATE 7/11/69 - , .. . .. 7/12 10/22 10/23 10/24 10/25 Production tests continue on D-1 well after workover. The well is gas lifting with tubing pressures of 150 psi and casing pressures'of. Il80 psi. A four hour test produced 1410 BO, 3 BW, 328 MCF gas.and used 259 HCF of lift gas. The gas oil .ratio is 231 cu. ft/bbl and the G.L.R. i s'. .415' cu. ft/bbl. Calculated on a 24 hour basis the daily rate is 8460 BOPD, 18 BWPD, 1968 MCF/D and 1554 MCF/D of lift gas. APl gravity 32.0° and BS&W cut -'0.2 of 1%. · . . . A five hour production test on D-1 well q~roduced 1474 BO, 3 BW, 393 MCF of gas. using 463 MCF of injection gas. The gas oil ratio is 266, the gas liquid ratio is .580. The tubin'g pressure is 150 psig and the casing press, ure 1280 psig. Open- choke.-. The AP$ gravity is 33.2° and the BS&W cut is 012 of 1%. Calculated -. 'production rate for 24 hours is 7025 BOPD, 14 BWD, 1887 MCF/D using 2220 HCF/D of lift gas. We will continue to test this well. j, Final test. .- · .. .. PB 11,998 . ' · - Move. d rig from D-19 to D-1 at mi.~hight. Rigged up Otis wireline and attempted to pull ball valve. Pulled wire line out of tools. Picked up fishing tools and recovered pulling tools. Ran in Well to pull ball valve. Casing pressure bled to 200 psi' Valves on 9-5/8" casing 'leaking. Tested Otis lubricator to 2000 psi. Valves on 9-5/8" casing leaking. Tested Otis lubricator to 2000 psi. Will' kill well with invert emulsion and pull tubing to change faulty X bushing on 9-5/8" casing. · - PB 11,998.. ' . . . Attempted tO pull ball valve for second time and pulled out-of rope socket. reheaded and ran in hole with overshot and mech-anical jars. Pulled out of roPe socket. Reheaded line and ran in hole with overshot and jars and recovered all wireline tools. Rigged up schlumberger and tested lubricator to 2500 psi - OK. Perforated 3-~" tubing from 11,096' to 11,097' 4 holes/ft. Rigged down Schlumberger· Started killing ~'~ell. K. illed well. _ . PB '11,998 . · Finished loading well wi'th mud. Installed back pressure valve. Removed ~nnas tree 'and installed BOps. Pulled tubing string. Set Baker ret. bridge plug at 550'. Started changing out X-bushing. PB 11,998 · Finished changing X-bushing, one seal in bushing was slightly' cut. The 12" ring gasket was deformed. Installed spool and tested X-bushing to 2500 psi. OK. Tested 9-5/8" casing to 2000 psi down to 550','OK. Pulled Baker model "C" ' bridge plug at 550'. Ran in hole with 4%" and 3~" tubing, landed in hanger. Removed BOPs. Installed Xmas tree. Tested tree to 5000 psi. Ok. Displaced hole with diesel oil and dropped setting ball. Set hydraulic packer. · 1. -6-70 DATE: HIS ' ORY OF OIL OR GAS W 'ELL WELL NO. 'D-1 LEASE PARISH STATE COUNTY EL£V. IToP OF OIL STRING ELECt. M £/~$UREMENTS TAKEN FROM IToP OF RO'FARY TAbLE~ ELEV. I [ORD. OR N~/,T ELEV. BLOCK SEC I~[ISTORY PREPARED BY TITLE FIELD TWP. R. ' Oo I! is o~r lhe greates! impodonce to have a complete history of the well. Use Ibis t'orm in reporling the his:ory of all important operations _ at the well, tocserher whh H;e do,us lhereof, including size of ha[e, s;ze and number of bits, complete description of ca'sing, cememing, fishing or drliilncj difficuhies, ~urveys, all tests, all completion operations and procedure, DATE .11/26 PB 11,998 :' . . SeE packer aE 11,121 it. Tested packer ~o 3000 ps~. Had sma}l leak. . .Circulated thru gas lift valves to wash s~.~m.,e.. Pressured tubing to 3000 psi. Had small leak ~.~ bled from 3000 psi t'o 2500,.ps~ in 25 min. Connected well to flow line and started unloading'we'il~i'' Released rig to D-3 at 7'30 10-26-69. Unloaded well. , o 1R~EV. 9-30-67 STATE O,F ALASKA OIL AND GAS CONSERVATION COMMITTEE SUBMIT IAI DEPLICATE MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS -5~API NUSIERICALL CODE 50-]33-20086 6. LE~SE DESiGNA/ION AND SERIAL NO. ^DL ]7594 ^ 887 'i'.- " 7. IF INDIAN, ..%LOT/-EE OR TRIBE NASIE 0IL ~ GAS ~ WELL WELL 0TH£R 2. NAME OF OPERATOR Union Oil Company of California* 3, ADDRESS OF OPERATOR 2805 Denali Street, Anchorage, Alaska 99503 4. LOCATION OF WELL Surface' 755.3' N and ]125.5' F' of SW Corner Sec. 6-8N-13W-SM Bottom Hole' 882.7' N and 3620.08' E of SW Corner Sec. 32-9N-13W-SM 8, UNIT,F.ki~M OR LEASE N.~.ME Tradinq Bay Unit 9. WELL NO. D-] (34-32) 10. FIELD A_ND POOL, OR WILDCAT McArthur River Hemlock 11. SEC., T., 1%, M., /BO~r'rOM HOLE OBO~CTIVE) Sec. 32-9N-13W-SM 12. PEI~ViIT NO. 67-80 REPORT TOTAL DEPTH AT END OF MONTI~. CHANGES IN HOLE SIZE, CASING AND CA/VIENTING JOBS INCLUDING DEPTH SET AND VOLUMES USED, P~RFORATIONS, ~S'rS ~ ~SULTS, FISHING JOBS, J~K ~ HO~ ~D SIDE-T~CKED HOLE AND ~Y O~ER SIGNIFICANT C~G~ IN ~O~ CO~ITIONS. Trading Bay Unit State D-l, March, 1968 3/] Made several runs with swages of different OD's jarring up and down through restriction. 3/2- 3/3 Ran lO' and 30' dummy perforating guns through restriction O.K. Commenced perforating. On run #7, gun stuck at 11,156' and pulled out of rope socket. Rigged up wireline fishing tools and recovered fish. Made 3 runs with swages jarring through restriction. Made 2 perforating runs. 3/4 Made 11 11,255' 11,695' foot wi additional perforating runs. Recap of all perforations is as follows: - 11,295', 11,320' - 11,410', 11,435' - 11,495', 11,515' - 11,670', - 11,845', and 11,865' - 11,921'. All perforations with 4 jets per th Lane-Wells Slimkone 2" carrier gun. 3/5 Set ball valves in both strings. Started flowing well at 1'35 p.m. 3-5-68. Released rig 12:00 noon 3-5-68. 3/8 Completed well through 3" chokes for 7589 BOPD, 8 BWPD, 2216 MCF/D, GOR 292, tubing pressure 175#, casing pressure "0", 32.5°API Total Depth' 12,071' MD and 9782' TVD j -.,. t,.? ,.,,,~ DIVISION OF M~[~S & MINE~L=, ANCHO~AG[ * Rarathon 0~] Company 7 Sub-~perato~,- Doily Varden Platform i4, I her;~ '~rtify t~t~ fd~go~ is trU~~d ~ ~. ~ , ..... Drilling Superintendent sm~__ ,., ~ 1,~[_~__~.'"". . ~ ~.~.~ 4/8/68 NOTE--Rep°rt on this form is required for each calendar month, regardless of the status of operations, an~ must be filed in duplicate with the Division of Mines & Minerals by the 15th of the succeeding month, unless othe~ise directed. A.P. I . CODE · 50-133-20068 D~- 12 Release Date 4-5-70 State of Alaska Department of Natural Resources DIVISION OF MINES AND MINE~-LS Petroleum Branch INDIVIDUAL WELL RECORD Sec. (6) 32 T.:._ tR. (Z3W) Z~-~ S · Meridian Pe rmi t No. 6 7-80 , , ,, _ ,, _. Issued i2-5-67 Slot 1, Leg A-2 Operator Union Oil Co. of Calif. Location (Surface) 755.3' FSL & 1!25.5' F!~, Sec. 6- Lease No. --: ~D~-1-7~-94 or Owner ..... _T.~ra~.ding .Baz_~n~it~ = . Loc. (Bottom) 660' FSL &.1980' FEL, Sec. 32 ,. Well No. D-t (34-,32) Area Dolly Varden (So. M,c. Arthur River) PBD 11,998' Spud Oate~:%:~4~?._=9__~67 ....... Df il ling Ceased ~ :-::-_T°tal Depth__!:._2,07_!'_~ Suspended___.___ _ _: ....... Abandoned ............ Elevation .... ~ _ _~._,.~ ......... ,__ _ ~,, ,~ . - , ............ Completed (F-~I~). Gas =_ 221:6.= ;_HCF/D, 3=5-68 _.. IP 7589 B/D, Bean~ ~9~2=_/64 CP ........ psi, Casing: Size ~ $×Cm_. _t. Perf: i 7z5 1600 ~3 3/8"~6~)'' ' 2527' 2~00 Z~,255-95 ~/~, 47~ ,43~¢) 9690 = ~Z30 9 9569 ~ 7"'29~) line_r_ ..= 12063~ ? 82~ 1!,695'-845' ..... Dual 3~" tbg6, on p~{'~4~i 130' & Surface L~st Tested Nam Grav 32.5° AP! Cut ..... _,p;_l._~_ _: % PRODUCTIVE HORI ZCrNS Depth Con ten ts ....... -- _-- * . - .-: -,:-. -_- - :z..-_" __ · ' · - ' ..= .... -,. ,.: _, z,, .L-LZ . _ . 'L ...."'. WELL STATUS Year Jan Feb Mar Apr May June July ~ ,,Aug Sept Oct : ,;_' '__',, ,, :;"~ :=:.:i~- __- =-. :: '.T:c-~'._ ' ..--:--'. _.-,'Z' -Z-.--_ _ - ..... .7 ,_.;._ --_~-(_',-' -- _ -:_-. _;.- : _..- ......... - ....... _ .... __- .:z · .. .. _ .. ,_.. _' z ........ _' _-- ' , Nov Dec , _,, _ ,, _ - _ :- ,- - =.___-...-- ~- Remarks: Contractor: Santa ==_..__,_,:- -_ .... _: ~_.. _~ _ _ _ ---~-~ Form No, P--4 }kEW. STATE OF ALASKA S~BMrr IN D~LmArS AND GAS CONSERVATION COMMll-FEE AtONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS 2. NAME OF OP~%ATOR n Union Oil Company of California* ADDRESS OF OPEI~,~ATOR 2805 OenaliStreet, Anchorage; Alaska 99503 LOCATION O'F WELL Surface- 755.3' N and 1125.5' E of SW corner Sec. 6-8N-13W-SM Bottom Hole: 882.7' N and 3620.08' E of SW corner Sec. 32-9N-13W-SM %. API NUZCERICAL CODE 50-133-20086 6. LF--kSE DESIGNATION AND SERIAL BIO, ADL 17594 A887 7. IF INDIAN, ALOTTEE OR TRIBE NA.AIE 8. L~NIT,FAE_M OR LEASE NAAIE Tradino Bav Unit 9. \VELL NO~' n-I ( 10, FIELD' A_ND POOL, OR WILDCAT McArthur River Hemlock 11. SEC., T., R., M.~ ~BOITOM HOLE OB0uEcrIVE~ Sec. 32-9N-13W-SM 12. P]~R/V~IT NO. 67-80 13, REPORT TOTAL DEPTH AT END OF MON'IX-I, CI-tA.NGES IN HOLE SI~,E, CASING A1N-D CE1ViENTING JOBS INCLUDING DEPTH SET AND VOLI/NIES USED, PERFORATIONS, TF, STS A/ND RESULTS, FISHING JOBS, JUNK IN HOLE A/MD SIDE-TIRakCKED HOLE AND A/%IY OTHER SIGNIFICANT CHA. AIGF_.S IN HOL$ CONDITIONS. Trading Bay Unit iS.ta.t.e D.-1,._...February, 1968 2/1 Cemented 9-5/8" casing through shoe with 836 sacks with 6% gel, 0.5% retarder, 0.Bg friction reducer mixed with inlet water and with 294 sacks mixed with fresh water {total ll30 sacks). Bumped plug with 1200#. Opened D~' Collar and r~'/~"~ circulated for 8 hours. Cemented 2nd stage through DV Colfa~-w-~th 836 sacks with 5g gel mixed with inlet water and with 100 sacks mixed with fresh water {total 936 sacks}. Bumped plug with 1500#. Cement to surface. 2/2 - 2/3 Nippled up. Tested BOP equipment to 3500# for 15 minutes, O.K. Drilled float collar. Tested DV collar and casing with 2000# for 15 minutes, O.K. 2/4 - 2/17 Drilled 8-1/2" hole to ll,g30'. Ran Lane-Wells Dual Induction and Dipmeter Logs. 2/18 - Drilled 8-1/2" hole to 12,071'. Ran Lane-Wells Dual Induction, Density, Gamma 2/20 Ray, Acoustic, and Proximity logs. Shot 25 sidewall samples and recovered 23. 2/21 Ran 58 its. 7" 29# N-80 X-line liner with shoe at 12,063' and top of liner at 9569' Cemented with 820 sacks with 1% friction reducer, 0.5% retarder mixed with ~resh water. Bumped plug with 2500#. Reversed out approximately 400 sacks. 2/22 - 2/24 Ran 8~1/2" bit and casing scraper to top of liner at 9569' Ran 6" bit and casing scraper to 11,998'. Tested liner lap with 2000# fo~ 30 minutes, O.K. Ran cement bond log. Displaced mud with sal.t water with diesel. Ran Lane-Wells gauge ring to 11,995'. 2/25 - Set 7" permanent packer on wireline at ll,130' {wireline measurements). Ran 2/29 dual strings of 3-l/2" OD 9.2# N-80 seal-loc'k tubing with 4 gas lift mandrels in the short string~nd 13'gas lift mandrels in the long string. Tagged 7" I / (Continued on Paae 2l th~t~the~oreg~j)e ¢ t~le~U~ oo~ct. Dist D ' ' ~ ~ I hereby ~rtify , ~ ~ . rlllln° SIO~ ~!~ '"- - ' ~ ~- ~T~ ~Npe!znnend,ent with the Division of ~ines & ~inerals by the 15th of the succeeding month, unless otherwise directed9 DIVISION OF MINES & MINERALS ANCHORAGE Form P~7 -, SUBMIT IN DUPL.'. ~I'ATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG* Effective: July 1, 1964 _.!. . · 5. LEASE DESIGNATION AND ~ERIAL' NO. f~i ADL 17594 '- A 887 I~' la. TYPE OF l~FELL: .. 0IL ~] GAS. WELL WE£L []] DRY D- Other b. TYPE OF COMPLETION: WELL NAME OF OPERATOR ~ Union Oil Company -. ' ADDRESS OF OPERATOR '507 W. Northern Lights Boulevard, Anchorage, Alaska 7. UNIT AGREEMENT NAME Tradinq Bay Unit $. FARM OR LEASE NAME Tradinq BaY Unit 9. WELL NO. 10. FIELD AND POOL, OR WILDCAT · McArthur River Field 11. SEC., T., R., M., OR BLOCK AND SURVEY OR. AREA 4. LOCATION OF WELL (Report location clearly and in accordance.with any State requirements)* Atsurface 755.3' N and 1125.5' E of SW';corner, Sec. 6-8N-13W SM ~.. At top prod. interval reported below At totaldepthd04.4' N and 169l 7' W of SE .. corner , Sec. 32-gN-lSW SM 881.4' N and 1314.7' W of SE ~4. PERM,TNO. DATE ISSUED corner, Sec. 32-gN-13W SM 67-80 I 12/5/67 '~'DATESPU"~E'I'XO''ATET'D'REAC"EDI~'DATECOMPL'(Re"dytoprod')12/19/67 2/18/68 3/5/68 Sec. 32-gN-13W SM 12. BOI~OUGH T 13. STATE Konai Pm.n. 18. ELEVATIONS (DF, RI~B, RT, OR, ETC.)* 116 RI above MLLW A1 'a -q ka 19. ELE¥. CASINGHEAD 77 above MLLW 20. TOTAL DEI~H, MD & TVD [ 21. PLUG, BAOE T.D., MD & ~n~ 22. IF MULTIPLE COMPL., 23. INTERVALS 12071-9782 I 11998-9727 HOW MAN,* DRILLEDBY RO~ARY TOOLS 12O71 CABLE: TOOLS 24. PRODUCING INTERVAL(S), OF THIS COMPLETION TOP, BOTTOM, NAME (MD AND TVD)* TOp - 11,255 MD - 9,163 TVD Bottom- 11,921 FiD - 9,669 TVD Hemlock 25.WAS DIRECTIONAL SURVEY MADE Yes 26. TYPE ELECTRIC AND OTHER LOGS RUN DIL, Density, GR-sonic, Hicro, Cement Bond 27. WAS WELL CORED no 28. CASING RECORD (Report all strings Set i~ well) CASINO SIZE WEIGHT, LB./FT. 20" 93 13-3/8" 61 '9-5/8" . DEPTH SET (MD) 716 2527 9690 40, 43.5 & 47 29. LINER RECORD TOP (MD) SIZE i::l I 9,569 26" HOLE SIZE __ CEMENTING RECORD AMOUNT PULLED .1.600 sacks none .2,10.0 sacks none :'206~ f s~a,C ks none ,..'~;. ~UBING RECORD " SCREEN (MD) ''"SIZE~' 'r;. .~DEPTH SET (MD) PACKER SET (MD) :' 'l:;" :r ..J', ..'...3,--1/2',[ I/'''' 1T,149" ' 1l ,13'0 9,502· . I .-.9,51o. ** a. Ci:D. siio¥.":':FR.~'bTV~., CEMENT SquEEzE, 'E'"rC. 17-1/2" 12-1/4" BOTTOM (MD) SACKS CEMENT* 12,063 820 31. PERFORATION RECORD (Interval, size a~d number) (4 jet shots per foot - 2" scallops) 11.,255-29.5; 11,320-410;. 11,435-495; 11,515-670; 11,695.-845; and 11,865-921. 82. DEPTH 'INTERVAL (MD) Al%IOUNT AND KIND OF MATERIAL USED .. none · 38.* PRODUCTION DATE FIRST PRODUCTION [PRODUCTION METHOD (Flowing, gas lift, pumping size and type of pump) I WELL STATUS (.Producing or .........I ] shut-in) 3/ FloWinq 5/68 " Producing FLOW.l.75T',,~ING PRESS. CASING PRESSURE0ri2"-HouRCALCULATED. >RATE OIL7 ,589BBL' [ GAS2,216,~'.' i WATER 8BBL' OIL32.5GRAVIT¥-API. o 60oF(CO'R'> 34. DISPOSITION OF GAS (Sold, used ~orfuel, ve~ted, etc.) TEST WITNESSED BY Fuel and vented Oohn g. Barber 35. LIST OF ATTACHMENTS 36. I hereby certify that the foregoing and attached i~)~formatlon is complete and correct as determined from all available records . ,.,",i , ' , ...... . . . .. , t \ ~1'}~ ~'2 : D~st. Dr~llin,g Superintendent SIGNED ~ a-,J/ //(' ' ] / b?'(/'/.'i,¢'~. ) ~ITLE DATE H. D. Mc~Iahan ..... *(See Instructions and Spaces for Additional Data on Reverse Side) ** Both tubing strings producing from Hemlock. 3/21/68 for each additional' interval to?be separately produced, showing:the-additional data pertinent to such interval. ~ - : ' ~. -' .~, : - _z ..... I$¢m 29: "Sacks c'e'zent": Attached supplemental records fo.r~is ~ell s~d show the details of any multiple'-~tage, cen~enting and the loCqtion"of the' ~menting tool. Item ~l]: Submi~ a separate completion report on this form £~-~each jnte~ to be separately produced. (See in'strg~.Ction for items 22 and 24 above.) INSTRUCTIONS ~r~l: This form is designed for Submitting a complete and c(~rre~ well completion report and log on all types Of Ia~d~-and leases to either a ~ederal agency or ~ State agency, or both, pursuant to applicable Feder~a.1 and/or State laws-and r'~egu~ations. Any'necessary special instructions concg:rni.~.~g the use of this~orm and the number of copies to be submitted, particularly with regard .tg' local, area, or regional proC~d',ures and practices, either _axe shown below or ~i!l b.a'~issued t~y, or may be obtained £ro~', the local Federal and/or' State office. See instructionsron items 22 and 24, and 33¢below regardin~ separate repor~ts for.-separate completions. If not filed prior td ;~he tinge this sum~mary record is submitted, copi~s- of all cur~ep.t]~v ~k:ailable logs_ (d~illers, geologists, sample an~l core an.aly_sis, ali t~ypes eIectric, etc. ), forma- tion and pressure tests, and directional surveys, should be attached hereto, to 'the~nt require~ by applicable Federal and/or-:State. 1~ and re~ulatio~.s. All attachments should be listed on--this form, see item .35. I$¢m 4: If there age no '~'pplicable State requirements, locations on Federal or Indian land should be described in accdrdance w~th Federal requirements. :~ Consult local: State or Federal office for specific instructions. ]~¢m ] $: Indicate Which elevation is used as reference (where not otherwise shown) for dePth measurements given in ~)i~he~ spaces on this form and:in any?attachment~:i [$¢m~ ~2 ~! ~4: If this well is~completed for separate productipnf~om more than one interval zone (multiple ffo~pletion~)-, so state in item~22, and in i~m 24.~show the producing interval, or intervals, .top (s), bottom (s) and name (s) (if any)~ .for only-the interval reported in item 33. Sul]~nit a' seParate re'po_ rt (page) on. tJai~ ~(~rm, .~dequately ide_.ntified, _ 37.: SUMMARY OF POROUS ZONES: . ~- ~ ~ _ ~ .: ' . '- ' ~ ' ~ SHOW ALL IMPORTANT ZONES OF POROSITY AND CONTENTS TJg[EREOJ~-, C_ORED~"INTERYAT~J~'-A/qD ALL- DRILL-S~EM ~ESTS, INCLU~O 38. :GEOLOGIC MAR~RS ~ .' D~PTH INTERVAL TE~ED, CUSHION USED, ~IME TOOL 0~N~ FLO~VIN~ ~D~ SHU~-IN ~SURES, AND RECOVE~S_ . ToP ] BOTTOM ' c ~: '~ ~ - DESCRIPTION, CONTENTS~ E~C. ~.,~ , ~ - TOP : . . . _ DATE iWELL NO March, .,1968. STATE' (34-3'2) D-1 LEASE Alaska- HISTORY OF OIL OR GAS wE L Trading Bay 'Uni ~ Kenai Borough SEC. ~ 6 -TWP ' : . . · . , . . KB ' ELEV[ +117 ' -MLLW J.'E. FoSher ELEV +74 45' " ' ~ ., ' HISTORY PREPARED ElY' · __ ELEV. +116 ' MLLW 'T,TL.~ Adv. Pet. Eng. GRD. OR MAT., ELEV. 8N r, . .. IToP OF Oil STRING MEASUREMENTS [.TOP OF ROTARY TABLE TAKEN FROM [ 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 operatiohs and procedure, etc. DATE 12/18/67 12/19 12/20- 12/21 12122 12/23 12/24 12/25 12/26- 12/28 12/29- 12/30 Rigging up drilling equipment. TD '571' - Spudded at 11:00 AM 12/119/67. Tagged bottom in piling at 375'. CircUlated out sea water and salt water mud. Drilled 12~" hole to 571'. · TD 720' - Drilled 12k" hole to 720'. 0p ed 12k,' hol to-17%'' to 26" ole from 410' to 720'. . . TD 720' - Ran 16 jts of. 20;' 94# H-40' 8rd ST&C Range 3 new caSing with float . .- collar at 669' and with shoe at 716'. Mixed and pumped 300 sacks cement when --.:.-?cement transfer line from storage pods to surge hopPer plugged. 'Unable to unplug line, so circulated out 300 sacks cement.- Replaced plugged line with 150' of hose. Cemented with 1600 sacks cement mixed with fresh water with 2% 'calcium chloride in last 400 sacks.. Good cement returns to-surface. 20" Casing Detail KB to Top Csg. 15 j ts 20" 94# H-40 8rd ST&C Csg. 1 Baker Duplex Float Collar 1 j t 20" 94# H-40 8rd ST&C CSg. 1 Baker Float Shoe - Effective From To 46.00' 0 -"'~-4-6-.00' 622.96' 46.00' - 668.96~ 2.35' 668.96' - 671.31'' 42.82' 671.31' - 714.13' 2.15' 714.13' - 716.28' 716.28' TD 720' - Cut 20" casing off 2' above wellroom floor and welded on casinghead. Tested casinghead with 1000#, OK. TD 720' - Installed BOP equipment. Ran Sperry Sun Gyro to 675'. CloSure at 675' was 3' N 47.o 49' E of the surface location .... · TD 820' - Drilled float cOllar and cement from 692-700'. Tested 20" casing and BOP equipment with 2000# for 15 minutes, OK.-Drilled cement, float shoe and cleaned out to 720'. Drill%d 12~" hole in new formation to 820~. TD ·2550' - Drilled and surveyed 12~" hole to 2,550'. Rigged up Lane-Wells and ran Dual Induction and Acoustic Logs. Opened 12~" hole to 17%" hole fr°m 720-1671'. TD 2,550"- Opened 12~" hole to 17%" hole from 1,671' t° 2,548'. Ran 60 its 13-3/8" 61# J-55 Range 3'Buttress casing with float collar at 2,486' and. with shoe at 2,527'. Cemented with 2100 sacks 15.6# slurry,, with 2% calcium chloride in last 400 sacks. Good returns while mixing~and during first 15 . of displacement, intermittent returns thereafter~ Ran 1" pipe in annulus - .'.. and found good cement'15' below casinghead. " .'"13-3/8" Casin~ Detail Effective . KB to Top Csg. . 45.00' 59 its 13-3/8" 61# J-55 Buttress" cSg~ 2441.10' 1 Baker Float Collar - ' : 1.65' 1 Jt 13-3/8" 61# J-55 Buttress cSg~'i. 37.55'' 1 Baker Shoe ! . 0 - -:~ ~ 45.00' . o. I0' 45.00' - ' 248" ' . 2486.10' - ~ 2487 · 75 ' 2487.75~ - 2525.30' .... · _ .-_: . ' 2.10' ' 2525.30' - _. 2527.40' . .'... ' ~- - ' - 2527.40' . : . · : .: .:: FO~M 484 R~..¥. 3--83 ,. DATE .. (34-32) WELL NO.. D-1 LEASE STATE MEASUREMENTS TAKEN FROm fToP OF OIL STRING TOP OF ROTARY TABLE__ GRD. OR MAT, - - D~/~.~_~.~.k ] . ~ ~l~. E:~D~"j~/:~-.~,,_~ FIELD Trading Bay Unit HISTORY OF Oil OR GAS WELL BLOCK Trading Bay Unit SEC. ' TWP r. - ~ARISH CouNTy ELEV. , · ELEV .... ELEV._ ELEV. ' 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 of casing, cementing, fishing or drilling difficulties, surveys, all te~ts, all completion operations and procedure, etc. ., . · DATE 196~ , i2/3i i/1/68 1/2- 1/3 1/4- 1/27 1/28 1/29 1/30 1/31 2/1 ' · , TD 2550' - Nippled up. Tested 20". 2000# x 1.2" 3000# spool· with 3000# for 15 minutes, OK.. . TD 3160' - Tagged cement plug at 2,484'. Drilled float collar and cement to 2,512'. Tested casing and BOP equipment with 3000# for 15 minutes, OK. Drilled'shoe and new formation to 3,160'. Picked up 285' of heavy wall drill pipe. .. - ,. TD 3478' - Drilled and surveyed 12~" hole. Lest DC power 40' off bottom; Circulated hole with BJ cementing unit. Down time 5~ hrs. TD 9700' - Drilled and surveyed 12~" hole to 9700'; Rigged up.Lane-Wells and ran Dual Induction, Gamma-Ray and Sonic Logs. TD 9700' - Made two unsuccessful attempts to run dipmeter log. Ran density log from 6,050~ up 'to 'bottom.of surface casing. Circulated and conditioned mud for 3 hours. ' TD 9700' - Ran dipmeter log. Shot and. recovered 9 sidewall samples. TD 9700' - Circulated and conditioned mud for 3 hours. Rigged up to run 9-.5/8" casing but could not run casing because of high winds .Ran in hole with bit. Waiting for wind to subSide. . ' 9689.93' . From ~ To 0 . ' ' 4~.55' 42. 55: - - 4860.60' 4860.60' 5856.22' 5856.22' - 5858.42' 5858 42' 6315.45' 8772.40' 9644.77" 9646.87' 9688.03" · - 6315.45' - 8772.40' - .~ 9644.77' - 9646.87' - 9688.03' - 9689.93' 9-5/8" Casing Detail ~ . - Effective KB to Top Csg .... - 42.55' 116 jts 9-5/8" 40# N-80 Buttress Csg. 4818.05'/ 24 its 9-5/8" 43.5# N-80 ~uttress Csg. 995.62" 1 DV Collar . ~- 2.20' 11 jts 9-5/8" 43.~5# N-80 Buttress'Csg. 457.03' 57 its 9-5/8" 47# N-80 Buttress Csg. '2456.95' 21 its 9-5/8" 47#' P-Il0 Buttress Csg. 872.37' 1 Float Collar .- ' 2.10' 1 Jt 9-5/8" 47# P-Il0 Buttress Csg. 41'16' 1 Float Shoe . 1.~0' surface. TD 9700' - Ran 230 jts 9-5/8" Range 3 butt'tess casing with DV collar at 5,856', float collar at 9,645' and float shoe at 9','690' TD 9700' - Preceded cement with 500 gallons of pre-flush. Cemented first stage with 836 sacks with 6% gel, 0.5% R-5 retarder, and 0.8% friction reducer mixed with Inlet water and with 294. sacks mixed with fresh water. Total' of 1130 sacks in first stage. -Bumped plug with 1200#. Dropped DV collar opening bomb and circulated thru DV colla, r. ' Had good cement returns for 10 to 12 minutes Circulated for a total' of 8 hours. Cemented second stage with 836 sacks with 5% gel .mixed with Inlet water and with 100 sacks mixed with fresh water. Total of 936 sacks in second stage. Bumped plug .with 1500#'. Had cement retUrns to FORM 484 REV. DATE · WELL NO. D-1 LEASE ~-/~~71~, -,~- ~ DIM HISTORY OF OIL OR GAS WELL Trading Bay Unit 'Parish STATE COUNTY ELEV. I ToP OF OiL. STRING __ ELEV., MEASUREMENTS I,.TOPOF ROTARY TABLE ' 'ELEV. TAKEN FROM /ORD. OR MATL ELEV. ' BLOCK SEC. HISTORY PREPARED BY T,~t.~ FIELD TWP It is of the greatest importance to have a complete history of the well. Use this form in reporting the his{;;.,'y of a;] im. portant operations at the well, together whh the dates thereof~ inclu~ling -size of hole, size 'and number 'of bits, complete descri:~.'ion-of casing, cemen{ing, fishing or drilling difficulties, surveys, ali tests, all completion operations and procedure, etc. 'DATE · 1968 2/2/68 2/3 214 2/5- 2/16 . 2/]]7 2/18- 2/20 2/21 2/22-24 TD 9700' - Nippled up. Tubing head would not hold pressure, removed and replaced, ring gasket. Pressured tubinghead and cameron spool with 2500# for 15 minutes, OK. Installed BOP equipment. Tested blind rams with 3500# for 15 minutes, OK. TD 9700' - Drilled DV collar at 5856". Tested DV collar with 2000# for 15 minutes, OK. Drilled~{loat collar and tested casing with 2000# for 15 minutes, TD 9915' - Drilled cement and shoe at 9690'. Drilled and Surveyed 84" hole to 9915'. TD 11,930' - Drilled and surveyed 84" hole to 11,930'. TD 12,000' - Ran Lane-Wells Dual Induction and dipmeter logs. · Drilled 8~" hole to 12,000'. TD 12,071' - Drilled and surveyed 8~" hole to 12,071'. Strapped drill pipe out of hole and made 10' .correction. Rigged Up'Lane-Wells and ran Dual Induction Log, Density Log, Gamma Ray, Acoustic Log, and Microlog fr°m TD tO bottom of 9-5/8" casing. Ran ih hole with drill pipe and conditioned mud for 24 hours. Reran Lane-Wells Acoustic log. Shot 25 and recovered 23 sidewall samples. Ran in hole with drill pipe and conditioned hole for 7 inch liner. · TD 12,071' - Ran 59 its 7" 29# N-80 X-line Range 3-csg with top of liner at 9,569 ft, landing collar at 12,017', and with shoe at 12,063 ft. .Cemented with 820 sacks with 1% D'31 friction reducer, 0.5% R-5 retarder mixed with fresh"~ate~. Bumped plhg with 2500#. -Reversed out approximately 400 sacks of cement. ; . -. . 7" Line~ Detail Effective KB to Top Liner .Packer . 9569.00' 1 Brown "SS" Packer with Tie Back Sleeve 8.95' 1 Brown "MC" Hydraulic Hanger 10.35' 1 Brown X-Over - 0.63' From 0 9569.00' 9577.95' 9588.30' 58 its 7" 29# N-80 X-line Csg. 1 Brown Landing Collar 1 jt 7" 29# N-80 X-line Csg. 1 Brown Type "V" Sho~ , 2427.77' 9588.93' 0.90' 12,016.70' 43.71'~ 12,017 60' 1~70'! 12,061.31' To - 9569.00' · - 9577.95' -- 9588.30' -- 9588.93' - '.12,016.70' - 12,017.60' - 11,061.31' - 11,063.0.1' PBTD 11,998' - Ran 8~" bit and Baker casing scraper to top of liner at 9,569'. Ran 6" bit and Baker casing scraper on 3~" and 5" drill pipe to 11,998'. Tested liner lap with 2000fi for 30 minutes, OK. Rigged up Lane-Wells and ran Cement Bond, Gamma Ray, and Collar Locator logs Ran 6" bit and' Baker casing scraper on 3~" and 5" drill pipe to 11,998'.. Displaced mud with salt water an~ displaced ~alt water with diesel. Total diesel used 750 barrels. Rigged up and ran Lane- Wells 7" gauge ring to 11,995'._ · · FORN 484 REV, 3--e3 DATE WELL NO D-1 ' STATE LEASE , ~TOP OF OIL STRING MEASUREMENTS / ~ToP OF ROTARY TABLE~ TAKEN FROM / [GRO. OR MAT · HISTOF~Y OF- OIL O,q GAS WELL . . BLOCK Trading .Bay Unit 'parish · SEC.- ' TWp. , · .. Ro COUNTY ., ELEV. ,. ELEV..~ ELEV: ELEV. HISTORY PREPARED 'BY TITLE . It ;s 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 2/25-27 PBTD 11,998' - Ran and set on wireline a 7" Guiberson AGT drillable permanent packer with tail pipe at 11,130', wireline measurements'. Rigged uP to run dual strings of 3%" OD Seal-Lock tubing with regular collars on the long string and speci~al clearanCe'collars.on the short string. The l°ng string. includes two USI circulating valves with 'sliding sleeves closed, 13 USI gas lift mandrels with Guiberson fluid operated gas lift valves, one Otis type "N" ball valve landing hiPple,-and one Otis flow coupling, The short string included a collett-type stinger, 4 Otis "CX" gas lift.mandrels, one Otis type "N" ball valve landing niPple, and one Otis flow coupling. Tagged Guiberson AGT 7" packer at 11,149' tubing measurements., 1.1,130' wireline . measurements. Pressured annulus to 500# to test lower packer seal assemblY, CK. Spaced out both strings. Guiberson RH-2 Hydraulic packer at 9.,502' tubing measurements. Otis. type "N" ball valve landing nipples at 344"-in long string and at 312' in short string. Indicated surface weight on AGT packer is 15,000# and on the RH-2 dual packer is 10,000#. Pulled tubing on-both strings to the ball valve landing nipples, and reran same installing %" stainles& steel control tubing. The control tUbing was tested to 5000# at each connection. Landed both strings. Tested seal assembly with pressure dowm long string at 100'0#, OK. Removed BOP equipment and installed Xmas tree. Tested Xmas tree and %" control lines to 5000#, OK. 3~" Short String_TUbing Detail* Effective KB to Top CIW Hanger 39.33' 3~'' Buttress 0 78' ' CIW Hanger 3%" 8rd x a. · 3½" Buttress x 3~" Seal-Lock X-over Nipple 0.33' 3~" 9.2# N-80 Seal-Lock Pup 3~" 9.2# N-80 Seal-Lock Pup 8 its 3½" 9.2# N-80 Seal-Lock 3½" Seal-Lock x 3~" .8rd X-over Nipple 3%" Otis Flow Coupling 8rd EUE : Otis "N" Ball 'Valve Landing Nipple 3½" 8rd x 3~" SL 87 j ts. 3~" 9.2# N-80 Seal-Lock 3~" Otis "CX" Mandrel Seal-Lock thrds 51 J ts 3½" 9.2~/ N-80 Seal-Lock 3>a'' 9.2# N-80 Seal-Lock Pup 3½" Otis "CX" Mandrel Seal-Lock thrds 43 j ts 3½" 9.2~ N-80 Seal-Lock 3~" Otis "CX" Mandrel Seal-Lock thrds 13 j ts 3~" 9.2f/ N-80 Seal-Lock 3~" Otis "CX" Mandrel Sea~-Lock thrds 106 j ts 3~" 9.2# .N-80 Seal-Lock . 3~" Seal-Lock x 3½" 8rd EUE Pup 3~" Guiberson Collett Stinger 8rd EUE~' . . . 12.14' 12.14' .243.18' 1.15' 3.00' 3.70 2659.79' 5.37' 1553.34' 10~08' 5,37' 1304.67' 5.37' 394.5~' . 5.37' 3237.72' 4.24' ' 0.37' 9502.01' * Seal-Lock Special ClearanceC°uplings ** Total length Collett 1.34' Cross Pin 1.42' up from bottom of Collett '. _ · From ~-.'.0t _ 39.33' - 40.11' - 40.44' - 52.58' - 64.72' - 307.90! - 309.05' - To 39~3' 40.11' 40.44' 52.58' 64.72' 307.90' 309.05' 312.05' 312.05' - 315,75' . 315.75' - 2 975.54' 2,975.54' - 2,980.91' 2,980.91' - 4,534.25' 4,534.25' - 4,544.33' 4,544.33' - 4,549.70' 4,549'.70' - 5,854.37' 5,854.37' - 5,859.74' 5,859.74' - 6,254.31' 6,254.31 ' 6,259.68' 6,259.68' - 9,497.40' 9,497.40" - 9,~01.64' .~'9,501.64' - 9,502 01' DATE WELL NO D-1 LEASE STATE IToP OF OiL STRING M EASUREM EN'TS {,TOP OF ROTARY TABLE TAKEN FROM [GRD. OR MAT ~v~':~,.._~..~.'¢~,'~',.%---------------~'-'~ ~IL ~~]['~,'~._. '~,f FIELD HISTORY OF OIL OR GAS WELL _ _ . - , :' BLOCK Trading' Bay unit ~ SEC. ' --TWP... ~ARISH COUNTY ELEV. , ELEV. e'LEV. ELEV. HISTORY PREPARED BY = TITL-E - . . It is of the greatest importance to have a complete history 'of the well. Use this form in reporting the history of all important °Perations at the well, together with the dates thereoft 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 32" Long string TUbing Detail* Effective KB to Top CIW Hanger . CIW Hanger 3%" 8rd x 32" Buttress 3½" Buttress x 3~"-Seal-Lock X-over l~ippte 3~" 9.2f/ N-80 Seal-Lock Pup 3~" 9.2~ N-80 Seal-Lock Pup ~ ' 3%" 9.2# N-80 Seal-Lock Pup 3~" 9.2# N-80 Seal-Lock'Pup 3~" 9.2~/ N-80 Seal-Lock Pup 3½" 9.2~/ N-80 Seal-Lock Pup 9 j ts 3~" 9.2# N-80 Seal-lock 3½" Seal-Lock. x 3½" 8rd X-over Nipple 3½'" Otis Flow Coupling 8rd EUE Otis "N" Ball Valve Landing NiPple 3%" 8rd x 3~" SL 6 j ts 3½" 9.2f~ N-80 Seal-Lock 3½" 9.2f/ N-80 Seal-Lock Pup 46 j ts 3%" 9.2f/ N-80 Seal-Lock 3½" 9.2f/ N-80 Seal-Lock Pup 36 j ts 3½" 9.2f/ N-80 Seal-Lock 3~" USI CF-2 Mandrel w/Guiberson MF-31 32 jts 3~" 9.2~/ N-'80 Seal-Lock 3~" USI CF-2 Mandrel w/Guiberson MF-31 29 jts 3%" 9.2~/ N-80 Seal-Lock 3½" USI CF-2 Mandrel w/Guiberson ~fF-31 27 j ts 3~" 9.2f/ N-80 Seal-Lock 3%" USI CF-2 Mandrel w/Guiberson M3-31 4 jts 32" 9.2# N-80 Seal-Lock 3~" 9.2~/ N-80 Seal-Lock PUp 39.33' 0.78' 0.33' 8.17' 8.12' 3.04' 3.09' 3.11' 3.08' 270.38' 1.15' 3.00' 3.70' 180.63' 6.06' 1,392.36' 6.10' 1,090.51' 3.69' 977.41 ' 3.69' 874.41 ' 3.69' 816.88' 3.69' 119 · 20' 3.18' From 0 ' 39.33' 40.11' 40.44' 48.61'i 56.73' 59.77' 62.86' 65.97' 69.05 ' 339.43' 340.58 ' To 39~3 ' 40.11' 40.44' 48.61' 56.73' 59.77' 62.86' 65.97' 69.05 ' 339.43' '340. 58 ' 343.58 ' ~" 9 2f/ N-80 Seal-Lock 16 its ~ z . 32" USI CF-2 Mandrel w/Guiberson MF-31 18 j ts 3~'" 9.2# N-80 Seal-Lock 3½" USI CF-2 Mandrel w/Guiberson MF-31 15 its 3%" 9.2f~ N-80 Seal-Lock 3~" USI CF-2 Mandrel w/Guiberson 14 its 3%" 9.2# N-80 Seal-Lock 3½" USI CF-2 Mandrel w/Guiberson MF-31 12 jts 3½" 9.2~/ N-80 Seal-Lock ' 3½" USI CF-2 Mandrel w/Guiberson MF-31 11 j ts 32" 9.2f/ N-80 Seal-Lock 3½= USI CF-2 Mandrel w/Guiberson MF-31 10 j ts 3½" 9.2f/ N-80 Seal-Lock 3½" USI CF-2 Mandrel w/G~iberson MF-31 10 jts 3½" 9.2# N-80 Seal-Lock . 3½" USI CF-2.Mandrel w/Guiberson MF-31 10 its 3½" 9.2f/ N-80 Seal-Lock 3½" USI CF-2 Mandrel w/Guiberson M-77 1' j t 32" 9.2# N-80 Seal-Lock 3½" USI Type "C" Circulating Valve 1 J t 3½" 9.2~/ N-80 Seal-Lock 3½" Seal-Lock x 3~" 8rd X-over Pup 343.58' - 347.28' 3~7.28' - 527.91' 527.91' - 533.97' 533.97' - 1,926.33' 1,926.33' - 1,932.43' 1,932.43' - 3.,022.94' 3,022.94' - 3,026.63' 3,026.63' - 4,004.04" 4,004.04' - 4,007.73' 4,007.~3~ - 4,882.14' 4,882.14' - 4,885.83' 4,885.83' - 5,702.7i' 5,702.71' - 5,706.40' 5,706.40' - 5,825.60' 5,825.60' - 5,828.78' 489.04' 5,828.78' - 6,317.82' 6,317.82' - "6,321;51' 6,321.51' - 6,874.40' 6,874-.40' - 6,878.09' 6,878.09' - 7,340,66' 7,340.66' - 7,344.35' 7-,344.35~ - 7,778.77' .7,778.77' - 7,782.46' 7,782.46' - 8,151.37' 8,151.37' - 8,155.06' 8,155.06' - 8,496.12' . 8,496.12" - 8,499.81' 8,499.81' - 8,809 75' 8,809.75' 8,813.44' 8,813.44' - 9,118.42' 9,i18.42' - 9,122.11' 9,122'11' - 9,429.88" 9,429.88' - 9,433.57' 9,433.57' - 9,465.20' 9,465 20' - 9,467.97' 9,467.97' 9,498,89' 9,498.89' - 9,502.01' 3.69' 55 2 · 89 ' 3.69' 462.57 ' 3.69' 434.42' 3.69' 368.91' 3.69' 341.06' 3.69' 30~. 94' 3.69' 304.98, 3.69' 307.77' 3.69' 31.63' 2.77' 30.92' 3.1.2' 9-5/8" Guiberson 3½" x 3½" RH-2 Hydraulic Pckr 8.18' 9,502.01' - 9,510.19' FOR~t 484~ REV. 3-63 DATE- -- PAGE 6 · . HISTORY OF OIL OR GAS WELL . - 'BLOCK SEC; WELL NO. D-1 LEASE'_ Trading Ba~ Unit. * . PARISH ' STATE COUNTY.' .. ELEV. , . I ToP Of Oil STRING MEASUREMENTS t~toP OF ROTARY TAB_I.E TAKEN FROm / /GRD. OR MATL · ~ ELEV. ELEV. ELEV. ~ HISTORY PREPARED BY · TITLE .FIELD , TWp It' is of the greatest importance to have a complete history, of the well. Use this f°rm. 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, s.urveys, all tests, all completion operations and procedure, etc. . DATE 1968 2/28 3¥' lOrd x 3¥' 8rd EUE X-over Coupling 0.50' 3¥' 8rd EUE x 3¥' Seal-Lock X-over Nipple .- 0.24' 53 its 3%" 9.2# N-80.Seal-LOck 1,605.02' 9,510;19' - 9,510'.69': ' 9,510'.69' - 9,510.93 9:510.93' - 11,115.95' 3%" USI Type "C" Circulating 'Valve 1 j t 3¥' 9.2# N-80 Seal-Lock 3½" Seal-Lock x 2-7/8" 8rd EuE Nipple 2-7/8" 8rd EUE Guiberson "P" Landing Cplg. 2-7/8" Guiberson "A" Seal Nipple w/4 "AI" Seal Units 2-7/8" Guiberson Mule Shoe 7" Guiberson 3¥' x 3½" AGT Drillable Pckr 4" 8rd ExtenSion Tube 4" .Srd x 2-7/8" 8rd EUE X-over Coupling 2-7/8" Otis X-nipple 8rd EUE 2-7/8" 6.4# N-80 8rd EUE Pup 2-7/8" Otis .X-nipple 8rd EUE 1 jt 2-7/8" 6.4# N-80 8rd EUE 2-7/8" Gudgeon 8rd EUE * Seal-Lock Standard Couplings 30.02' 1.05' 11,196.17' 2.77' 11,115.95' - ti,1!8.72' 29.88' -11,118.72' - 11,148.60' 0,40' '11,148.60' - 11'149.00' 0.25' 11,149.00' - 11,149.25' 6.03' In Packer 0.78'. In Packer 2.65 11,149.25' - 11,151.90' 5.45' 11,151~90' - 11,157.35' 0.48' 11,15L,35' - 11,157.83' 0.39' 11,157.83' - 11,158.22' 6.00' 11,158.22' - 11,164.22' 0.88' 11,164.22' - 11,165.10' 11;165.10' - 11,195.12' 11,195~12'.- 11,196.17' PBTD 11,998' - Retrieved ball valve dun~nies from both tubing strings. Circulated down ~" control lines with 1500#. Pressured long string to 3500# to set Guiberson RH-2 hydraulic packer. Did not see surface indication that packer set. Pressured short string to 1000# to test packer. Pressure decreased to 725# in 5 minutes with annulus flowingl ½" stream. Pressured annulus to I000# with pressure holding OK for 5 minutes. Pressured short string to 1000# with pressure decreasing to 725# in 5 minutes. Annulus flowing ~" stream. Retested tubinghead to 5000#, OK. Ran and set Otis "X" plug in Otis "CX" mandrel at 6,254'. Ran Otis "CX" mandrel closing tool and checked m~ndrels. at 5854', 4544', and 2976' to see that .sliding sleeves were closed, pressured short string to 1400#. Otis "X'".plug pumped out of CX mandrel. Pressure · decreased rapidly with a 2" stream ~lowing fr°m annulus. 'Retrieved otis "X" plug off cross pin at 9501'. Dressed plug and set plug in mandrel at 6254!. Ran Otis "CX" mandrel closing tool. and checked to see that all sliding sleeves were closed. Pressured short string to 1000#. Pressure decreased rapidly with a 2" stream flowing out of the annulus. Pressured annulus to 1000# which decreased to 990# in 15 minutes. Pulled Otis "X" plug from mandrel and pressured annulus to 1000#. Pressure decreased to 950# in 15 minutes and. t-o 920# in 30 minutes. Ran Otis "CX" mandrel closing tool and checked to see that all sliding sleeves were closed. Pressured annulus to 1000# which decreased to 950# in 15 minutes and tq 920# in 30 minutes. ~Ran USI shifting-tool in long. string and opened sliding sleeve in circulating valve at 11,116'. Annulus pressure decreased to 750# in 3 hrs. Repressured casing to 1000# with pressure decreasing to 750# in 3 hrs. FORI~ 484 REV. :~-~'"' DA.TE PAGE 7 HISTORY OF O!L OR GAS WELL FIELD WELL NO. STATE MEASUREMENTS TAKEN FROM D- 1 LEASE Trading Bay Unit PARISH . _ 'COUNTY BLOCK . SEC.- . , TWP fToP OF OIL STRING ~ TOP OF ROTARY TABLE GRD. OR MATi ELEV. ~ ELEV., ELEV. ELEV., , 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, to~,,ther with the dates thereof, including size of hale, s'ize and number of bits, complete description of casing, cementing, fishing ar {-:..'... -.-' ,::;:-~, ~urv,vs, all tests, all completion operations and procedure, etc. ' -' DATE 1968 2/29 3/1 3/2 3/3 PBTD 11,998' - Rigged up Lane-Wells and ran 2" Slimkone perforating ghn which stopped at 11,156'. Gun stuck but was worked loose. Mark'ings on bottom of perforation gun indicated a maximum ID of 1.875". Ran Otis. long tapered swage, maximum OD 1.90" on oil jars, meChanical jars, and sinker bars. Set swage down on restriction at 11,156'.. Swage fell through restriction after jarring on swage 30 minutes. Worked swage through restriction several times jarring-in both direct, i~ns. Ran short tapered swage with maximum OD of 2.30" on jars and sinker bars. Jarred for 1~ hours but could not get swage through restriction. Pulled swage out of hole. Markings-on swage showed a maximum ID of restriction of 1.95". Built up 1.90" OD lbng tapered swage to 2.10" OD with tungsten carbide and ran in hole Jarred swage through restriction in 10 minutes. Worked swage through restriction several times and pulled out of hole. Ran short tapered 2.30" OD swage. Jarred on restriction 35 minutes with no success. Pulled out of hole leaving 18.36' of fish in hole including short. tapered swage, sinker bars, oil jars, and mechanical jars. Tools had backed off while coming out of hole. Ran in hole with 1.5" overshot latched onto and recovered fish. Markings on swage showed restriction ID 'of 2.15". . . PBTD 11,998' - Ran 2.20" OD extra long tapered swage. Jarred on restriction until swage worked through, then jarred up and down 'in and out of restriction for one hour. Ran 2.30" OD short tapered swage.~ Jarred on restriction 1~ hours until swage worked through. Jarred up and down through restriction four times. Pulled out of hole. Ran dummy perforating gun with 2" OD and 11_~' length. Gun would not go through restriction. Laid down dum~ny gun. Built up 2.20" OD extra long tapered swage with 'four rings of tungsten carbide on long taper. 'Ran swage and jarred on restriction 2 hours with no success. Swage stuck and pulled out of rope socket. Left 55.3'-of fish in hole. Made up fishing tools and recovered fish. Added hard facing to 2.20" OD extra long tapered swage and jarred 1~ hours on restriction with no success Pulled out of hole and. added hard facing to swage. Ran swage and jarred through restriction four times.- · .. PBTD 11,998' - Ran 10' dummy perforating gun with gun going through restriction OK. Ran 30' dummy gun with gun going through restriction OK. Pressured annulus to 1000~r~. 'Ran Lane-Wells 2" Slimkone perforating gun and perforated from 11,891-11,921'. Could not get gun. beIow 11,921'. Tubing pressure increased from 0 to 500~/. Ran 30' perforating gun which stopped at 11,155'. Pulled out of hole and welded 2" guide swage on bottom of gun' and reran same. Gun went· through restriction with no trouble and perforated from 11,865-11,891'. Made four additional perforating runs perforating from 11,815-11,845', 11,775-11,815',' 11,735-11,775' and 11,695-11,735' On perforating run ~/7, gun stopped at 1t,165'. 'Attempted to.wqrk gun through· And gu~ becmma stuck. Pulled out of' rope socket. . ' · · PBTD 11,998' - Made up wireline fishing tools with overshot, ran in and recovered fish. Ran extra long tapered swage with maximum OD of 2.25" and jarred 1~ hours with no success. Ran 30' perforating gun with short swage on bottom and jarred 30 minutes with no success. Ran t.82" swage and jarred through restriction. Ran up and down through restriction ten times. Tools hung up several times going both ways and at several different depths.. I.t appeared that a .piece of iron had been knocked loose and was worked out of tail pi~e. Ran 2.25" swage and worked · . FORM 484 REV. 3--63 , DATE WELL NO.. I)-1 · LEASE STATE HISTORY 'OF O!L'OR .GAS Trading Bay Unit PA R I.S H COUNTY M EASUREM ENTS TAKEN FROm · ELEV.,__ ~ToP OF OIL STRING HISTORy PREPARED BY bLOCK SEC. . t . . ELEV. __ TOP OF ROTARY TABLE__ ELEV. TITLE [grO. OR MAT ELEV. : : : . It is of the greatest importance fo have a complete, history of the well: Use this form in reporting the hist°fy .of all important operations - at the well, together with the dates thereof, including size of hole, size and number'°t~ bits, complete description of casing, cementing; fishing or drilling difficulties, surveys, all tests, all completion operations and procedure, etc. ,, 3/4 3/5 3/6 3/7 'through restriction several times. Ran 40' perforating gun and perforated.from . 11,515-11,535'. Bottom 20' of gun did not fire. perforated from 11,255-11,295'. Casing pressure 700#, long String tubing, pressure 550#, and short string tubing 650~r. . pressure PBTD 11,998' - Made 9 additional perforating runs and perfOrated frOm 11,320-11'410 11,435-11,495' and 11,535-11,670' All perforating was done with Lane-Wells 2" Slimkone carrier ~'un with 4 slimjim jets per foot~ A recap of the Hemlock perforations is as follows: 11,255-1i,295'~ 11,320-11,410', 11,435'-11',495', 11,515-11,670' 11 695-11 845' and I1 865-11,921' Ran shifting tool on , , ~ , , · wireline and checked to see that sliding sleeves on all gas lift mandrels and circulating valves were in cOrrect position'. pressure 108#.' PBTD 11,998' - Set and tested Otis ball valves, OK. Released 'rig. at 12:00 NOon 3/5/68 Placed well on production through both strings of tubing through 24/64" chokes on each string-at 1:35 PM 3/5/68. Tubing pressure.600# and casing pressure 725#. Bypassing separator on platform and going directly to shore through one pipeline. Well flowed diesel and water then Oil and mud. Gradually opened chokes to 34/64". Fluid arrived onshore at 8 PM.' Tested well for 6 hour through 34/64" choke. Well made 4,125 bbls of oil per day, with cut decreasing from 14% to 0.2% during, the test period. TUbing pressure 450#, casing Pressure 875#, and shipping pipeline pressure 115#. ' All pressures rema. ined constant during the test period. 'Corrected Gravity 33.,2 :deg AP1. PBTD 11,998' - Four hour test with separators on platform bypassed and all fluid going through one pipeline: 54/64" chokes, 6368 BO/D, 64 bbls BS&W/D, cut 0.1% on platform and 1% on shore, tubing pressure 305#, casing Pressure 85#, pipeline pressure 140#. Switched flow through platform separator at 10:15 AM. Set all level controls and safety equipment on both test and group separators. Split flow with oil going to shore through one pipeline and gas to shore through the other pipeline. Six hour s%abilized test; 96/64" chokes, 7,610 BO/D, 23 BW/D, cut 0.1% on 'platform and 0.3% 'on shore, GOR 278, TP 195#' CP decrease~ gradually to 75#, separator pressure 115#, oil pipeline pressure 90#, gas pipeline ' pressure 40#. . . PBTD 11,998' - Nine hour test into tanks at Onshore Site; 192/64" chokes, 7,608 BO/D, 15 BW/D, cut 0.2%, GOR 330, TP 150#' CP zero, gravity 32.7°API, oil pipeline pressure 50#, gas pipeline preSsure 57#, and platform separator pressure 65#. Sixteen hour test through meter at Onshore Site; 192/64" chokes, 7,589 BO/D, 8 BW/D, cut 0.1%, GOR 292, TP 175#, CP zero, gravitY 32,5© AP1, oil pipeline pressure 85~, gas pipeline pressuSa 51#, and platfoTM separator · Bit No. 1 RR 2 HO#1 HO#2 H~I RR 3 3 RR 4 5 6 H~3 7- 7RR 8 9 10 11 12 13 14 15 16 17 18 19. 20- 21 22 23. 24 '25 26 27 28 29 3O 31 32 33 34 35 36 37 38 '39 4O 41 42 43 44 45 46 47 48 49 5O 51 52 53 54 55 56 57 58 59 ' 6O 61 62 Size 12% 12% 17% 26 17% 12% 12% 12% 12,% 17% 12% 12-% 12,% 12% 12% 12% 12% 12,% 12% 12,% 12% 12% 12,% 12,% 12% 12% 12% 12% 12% 12,% 12% 12% 12,% 12% 12,% 12% 12% 12,% '12,% 12% 12% .8% 8% 8% 8%, 6 Make HTC' HTC Sec Sec Sec HTC HTC Reed HTC Reed Sec HTC HTC HTC HTC HTC HTC HTC HTC Globe HTC Reed HTC HTC HTC HTC HTC Reed Reed Sec Sec Reed Reed Reed Reed Reed Reed Reed Reed Reed Reed Sec ' Reed HTC Reed HTC HTC Reed Reed Reed Reed Reed Reed Reed HTC HTC HTC Reed Reed HTC Reed Reed Reed Reed Reed Reed HTC TRADING BAY UNIT D-I; PAGE 9 . Footage HoUrs Condition Welded to h°le Opener 424 720 . ~- 296 - 410 720" 3110. 3 GOod 410 720 310- 8 Good 671 720 49 -4% ~ Good 720 -820 100 1~ Good 820 964 144 . 5 -Dull 964 1668 . 704 6 Dull 1668 1877 209 3 . Fair 1877 2550 673 7 Dull 720 ' 2548 ~ 1828., 16~ Med Dul1 2550 2766 216 3 G°od -2766 3164 398 6,% T2-B1 3164 3341 -177 14 T2-B1 3341 3400 59 3 '3400 4133 ' 733 8~ T2-B2 4133 4262 129 6 Dull 4262 4767 505 4767 4919 152 5 4919 5043 1-24 3- 31/4 5043 . 5-106 63 2-3/4 5106 5466 360 5466 5732 262 12-3/4 T6-D2 5732 6358 626 6358 6827 469 I7~ T6-B4 6827 7172 ~345 14-3/~ Dull 7172 7452 280 15% Dull 7452 7677 ~ 225 12-3/4 Dull 7677 7888 211 8% Dull 7888 8128 240 I2% T3-B2 8128 8217 89 3% T2-B2 8217 8364 ,_47 8364 8500 136 6 ' T5-D3 8500 8690 190 12i T4-D3 8690 8788 98 5-3/4 T2-BI 8788 8903 115 7½ T3-B2 8903 8913 10 5 T6-B3 8913 8970 57 6 Dull 8970 9106 136 9 T3-B2 9106 9248 142 924'8 9359 111 9359 9459 100 6'3/4 T3-B1 9459 9614 155 8-3/4 T3-B3 9614 9700 86 5-3/4 T3-D1 9700 9766 66 4% T4~B2 9,766 9960 194 11 T5-B2 9960 10,082 12~_ 4-3/4 T3-B1 10,08h 10,264 182 8-3/4 T6-B3' 10,264 10,392 128 -~ 8 T8-B~2 10,392 10,517 125 7% T8-B2 10,517 10,553 36 ..4%' T1-B2 10,553 10,652 99 6% T4-B4 10,652 10,753 i01 4% T7~B5 10,753 10,843 90 5 T5-B2 10,843 10,926 83 - 3-3/4 T$-B5 10,926 iI~121 i 195 11,121 11,252 '~ 131 8 11,252 11,364 112 11,364 11,423 59 ' 6 TS-B4 11,423 11,492 69 8 T6-B3 11,492 11,562 70 6 T8-B3 11~562 11,619 57 11,619 11,684 65 7 T8-B5 11,684 11,764 80 7 T6-B4 11,764 11,8-31- · 67 6% ' TS-B5 11,831 11,930 ' 99 8~ TS-B5 11,930 12,061 131 10 T4-B5 Clean out 7"-liner BIT :RECORD - . Type ' On Off x-3 B-17 ~-26 ~-17 X-3 STSJ X-3 ST3J B-17 X-3 X-3~ X-3 X-3 X-3 X-3 X-3 X-3 M-2 X-3 S~ STIAG XDG XDG XDG XDG STIAG STIAG S4TG S4TG ST1AG ST1AG ST1AG ST1AG STIAG ' ST1AG ST1AG STIAG ST1AG ST1AG S4TG ST1AG XDG ST1AG XDG ST1AG ST1AG ST1AG YHG YS IG YSIG STiAO XDG, XDG YHG YHG XDG YSIG YHG YHG YHG YMG YMG SYMB0t O.~ SLRVICE REPORT , of SUB-SURFACE DIRECTIONAL SURVEY MARATHON OOM PANY ,'r. B.u. D-I COOK WELL NAME IN L ET, ALASKA LOCATION JOB NUMBER' TYPE OF SURVEY DATE AM-121067 SINGLE SHOT DEC.-FEB. SURVEY BY ANCHORAGE OFRCE LITHO BY EASTCO IN U. S. A. , , , , ~,.,oL o, ~E~,c, ~ JOB NO. . ~'~-12-1067 DAT~ De~ l_p67.Feb 1968 L c.,c~ .~. 5 1056 '00 7~O0, 10~ 72 15 85 N27'OO'E 2~,8¢ r 1 89 31 6 i~6 O0 8o i ? t2~0 i~ 9~3o, 12h6'31 l? i6 N30~OO,E ~l 38I 16 )2 · 8 1412 O0 12~30' ~Oh 62 34 38 9 1543 ~ 15000' 1531 15 33 90 i 56 08 65o , .21~ ~ 2~00, 2~ ?¢. 2328 t~ 29'00~ 2255 82 89 20 I 16 2550 ~ 35~00' 2437 ~ 127 J4 N ~OO'E 516~46 17 2~7 ~ 41~00' 2631 ~ 168 62 ~ 8~'S 68J~44 · ~ 1~ LO 18 2870 ~ 40'45' 2679 ~37 19 2965 ~ ~41~00' 2~1 07 62 33 20 3090 ~ 15' 2845 ~ 82 i41 N6~'S 868~O8 ¢ 181 ~2 21 3154 ~ ~'45~ 2892 80 42 62 N 8~'E 910 29 187 2.5 22 3247 ,~ 4I~30' 2962 46 61 62 ~N-:'5*OO'E 9~ 68 192 62 23 3J~ OO 42~00' 3032 '31 62 90 N 5~'~IE 1034 34 198 LO 24 ~417 ,~ 42~45~ 3088 12 51 59 NIO~'E 1085. 1% 207 D6 -25 J477 ~ 43~00' 3132 O0 40 92 ~'~-O~'E !125i 45 ~' 2~ 16 , RECORD or SURVEY '°' °' "'~' JOB NO. AM-I~106? ,, 27 3631 ~ 43'15' 32~ 36 63 1~'00'~ 1228 7 233 29 3883 ~ ~o~, 3425 fi2 ~ 61 ~0~,~ ~~64 267 30 3976 ~ ~°oo, 3492 51 64 61 NlO~,~ ~ ~27 278 93 3~ 4070 O0 44000' 3560 12 65 30 N~I°~'~ ~28 ~37 291 ~9 4167 O0 ~' 36~ 90 23 62 ~2'00'~ 1594 304 65 3 4230 ~ 41~, 3676 ~1 2~ oo ~5-~,E 1635 315 ~5 36 h26~ ~ 39°45' 3700 74 19 82 N16°~'~ 1654 08 320 61 37 4291 ~ 38~45' 3724 ~4 ~8 78 ~6°~,g 1672 13 3~ 4353 oo 38'15' 3772 83 38 38 N20'~'~ 1708 20 338 92 ~6 ~ 38030' 3882 ~3 39 22 N17'~'~ ~745 ~ 350 39 o0 .8 vo 4572 ~ 39~o0' 3943 36 39'65 N20'~'E 1837~96 383 ~6 47~ O0 39~30, 4088 68 59 79 N18'~'E 1951 70 419 83 4887 ~ 39~' ~87 ~7 ~92 N22o~'E 2025 ~80 ~9 77 46 5043 ~ 39~O0' 43~ ~6 ~9 78 N24~'E' 2~5]01 490 21 47 5123 ~ 37030' 4372 23 48 70 N30'~,E 2157 18 ~8 5156 OO 37~45' 43~8 ~2 20 [20 N30'~'E 2174 ~67 : ~9 5186 O0 38'00' ~21 ~6 ~8 47 N30'OO'E 2190 ~67 533 ~90 , 563 16 ~-50 5279 OO 39~' ~94 23 58 52 N30'~'E' 22~ ~35 RECORD OF SURVEY JOB NO._ AM-12-106? DATE Dec 1967,- ~'eh. 1968 _ c.~c~ .Y. MEASURED DRIFT TRUE '"------'-- ATION DEPTH ANGLE VERTICAL COURSE D"IFT "E C T A N G U L A R C O O R DIN A T E DEPTH DEVIATION DIRE~"FION · . , NORTH i SOUTH I EAST I WEST 51 5373 OO 40°OO' 4566:}23 60! 42 N30°OO'g 2293167 53 5577io* 37'OO' ' 75 N30°OO'g 2341108 620 23 N31°OO'g 2402114 657 54 5668 oo 38°00' 479838 5603 N30*OO,g 2450166 t 685. 56 5858'00 37°15' 494979 7627 N31'OO,g 2549. tO6 7~.~ ~l7 57 5.985[00 37°45' 5050: 21 75 NSI°OO,E 2615 71 784 44 N32°OO'~ 23 826 ~18 59 62651OO 39000' 526849 96191 N320OO,?~ 2764!41 877 ~53 60 6357, OO 38'30, 5340 ~49 57i27 N34°OO,~ 2811'89 i 90956 61 6482 O0 38°15' 543865 7739 N33°OO'F, ' 287680 t~ 951 ~71 62 6632 OO 38°15' 555645 92i 87 N340OO'g 2953179 100364 63 6795 OO 37°00' 568662 9809 N35°OO'E 303415 1059 ~O ~ 6951 OO 37°OO' 5811.20 93.88 N36°OO'g 311010 111538 ~-55 7043jOO 37°30, 588419 56' O1 M38°OO,g 315424 114957 I , 66 7172 OO 37015' 5986 78 7808 N37°OO'g 321659 ] 1196 .56 67 7302 OO 37°00' 609069 7823 N38°OO'E 3278124 I 124473 68 7452 OO 36°15' 6211165 88j 70 N39°OO'E 334717 1300 69 7539 OO 38°00' 6280'21 5357 N41°OO'E 3387i'60 1335 ~O5 7O 7666 OO 4l°OO' 6376 06 8332 N39°OO'E 3452{35 138813 V 71 7765 O0 41o OO, 6450 78 6495 N40° OO 'g 3502 10 '! 1~29 ~8 72 7888 OO 40°30' 6544 31 79~ 88 N40°OO'E 3563!29 1481 23 7473 81257999 ooOO 38'1540° O0" 67306629 6934 7135 N40°OO'E 3617194 1527 }9 O1 N40°OO,~ 3677 70 1577 ~3 75 820300 38045' 6791 52 4788i82 N43ooo,E 3713 41 ~ 1610 ~3 FORM NO. i i i i i i i i ~ir RECORD OF SURVEY JOB NO. i~m-12-IO67 DATE r~__e: !967- Feb: 19~ , , , , MEASURED DRI~ TRU~ COURS~ DRI~ R E CTA N G U LA R C OO R D ! N A VE~CAL , , ~-'TION DE~H ANGLE DE~H DEVIA~ON DIRE~N ~H 1 ~UTH I ~ST ! 78 8~37 oo 38~~ 697~ o~ 9~ N~°~,~ '38~o o8 I ~7o89h 79 85~ ~ 37'~ 7o~ ~o 38~3 ffh3°~ 3~7 97 80 85~ ~ 37030' 7072 ~ 36 53 N43°~'~ 3874 ~69 i 1~9 85 81 8639~ 38~3O' ~ 63 49 18 ~q42°~'~' ~11 ~24 } 1792 76 82 8721 OO ~00' ~98 35 51 ~ N~°~'~ 3948. 36 [ 1828~61 83 87~ ~ 39'30' 7246 96 40 O7 N47~'~ 3995 i69 185792 84 88~ ~ 40~30' 7290 30 37 O2 ~14~'E 40~ ~94 1885~OO 85 8903 ~ ~*OO, 7337 ~ 40~ ~ N50°OO,JS 4027 '09 1916~16 I ~ 8955 ~ 40030' .7376 63 33 77 ~47'~'E 4050 12 1940 ~ 87 9050 OO ~' 7~8 33 62 33 ~'~45°~'S 4~4 ~I9 1984 ~93 88 9106 OO ~45' 7490 ~ 37~29 I'i47°~'S ~9 ~62 2012 20 ) 9154 ~ ~*OO' ~25 .78 32~12 N46~'S 41~ 93 2035 21 "~90 9248 OO 42000' 7595 :63 62'90 N46°~,~ ~85 63 2080 45 91 9341 ~ ~'45' 76~ O2 61 93 ~N46'~'~ 4228 65 ] 2125 ~ 92 9404 OO ~*~' ~2 57 ~ 33 N45'~'~ 4257 87~ 2154 22 93 9459 ~ 41~' 7754 O8 '36 ~ N46~'~ 4282 94 2180 t8 94 9551 OO 40~15' 7824 29 59 ~ N46~'S 4324 23 ~ 2222 94 ~ ~ ~ 70~ 2252h0 95 96~ OO 39045' 7872 72 40 28 ~47 ~'~ 4351 , . ! 96 9700 ~ 39°3O' ~39 08 ~': .~47°~'~ 4389 O1 2292 97 9768 ~ 39030' ~91 J4 43 25 ~4~'~ hhJ8 51 2324 98 9876 ~ 39°~' 80~ h7 67 96 N~°~'E ~ ~86 2373 1~ 10019 ~ 37045' ~88 31 36 12 N~o~,g 4522 2~O O4 RECORD OF SURVEY ~,.,o~ o,W~~c` JOB NO. ~M~.12-1-6? DATE Dec. 1967 - TRuE COUPE DRI~ R E CTAN G U LA R COO R D IN A ' ~ON M EASU RED DRI~ VE~CAL . 101 1~82 OO 38'00' 8237 95 -38 N49*OO'E ~ 2 ~ 31 102 10176 ~ 38~' 8312 02 57~ ~ N48~'.E 2 32 103 102~ OO 37°~' 8382 30 52~96 .~9~'E 4621~42 2552 ~29 104 10370 OO 37~45' ~ ~ ~ 89 N49*OO'E 4~3199 2~1 26 105 10465 ~ 38°~, 8540 )7 58 49 N49~'E 4702~37 ~ 2~5 ~40 107 1~52 OO 37~O0' ~89 85 59 58 N49'~'~ 4~6~ 2730 108 10753 ~ 36'45' 87~ i78 ~ 43 N48°~'E 4~7 2775 1~ 10843 ~ 37'~' 8~2 65 54 [16 N47~'E 4853 98 2~5 32 110 10926 ~ 38'~, 8908 O5 51 10 N47'~'E 4888 83 2852 1~ 11OOO OO 38~' ~ 36 45 56 N47~'E 4919 90= 28~ O1 112- 11121 OO 38'15' 9061 38 74 91 N46~'E 49~ 94 2939 89 ~13 11252 ~ 39~, 9163 18 82 ~ N45~'E 5030 23 2~8i18 ~4 113~ OO 39~1%, 9249 91 ~ 86 N44'~'E 50~ 20 3047~ ~5 1~23 ~ 40~30, 9294 77 38 31 N~'~ 5108~ 76 3074 O2 I ~6 1~92 ~ 40'3O' 9347 24 ~ ~ N45'~'E 5~O 45 3105 117 ~552 ~ 39'45' 9393 37 ~8 36 N~~'~ 5168 O4 3132 36 ~8 11619 ~ 40~' 94~ 69 43 O7 N45'~'E ~98 49 3162 81 ~9 11684 O0 40~15' 9494 30 42 ~ N46'~'~ 5227~67 3193 ~O2 120 11764 O0 40'45, ~54 91 52 22 N45'~,E 52~ ~59 32~ ~94 121 11831 OO 42'~' 9~4 ~70 44 83 N45'~'E 5296 29 3261 122 11930 ~ ~' 9678 27 ~ 24 N45oOO'E ~3 13 3308 48 123 120~ O0 41~' 9784 68 92 51 N46~'E 5407 40 33~ O2 Clors~me N 32* O1' E 6375~73 SUNDRY NOTICES AND REPORTS ON WELLS ,/ 1. DRILLING WELL [] COMPLETED WELL ~ OTHER [] 2. Name of Operator 7. Permit No. Union Oil Company of California* 67-80 3. Address Post Office Box 6247, Anchorage AK 99502 4. Location of Well Surface: Leg A-2, Cond #1, Dolly Varden Platform 755' FSL, 1126' FWL, Sec. 6-8NI13W-SM 5. Elevation in feet (indicate KB, DF, etc.) 106' KB above MSL 6. Lease Designation and Serial No. ADL-17594 8. APl Number 5o- 733-20086 9. Unit or Lease Name Trading Bay Unit 10. Well Number D-1 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 Ca'sing [] 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). Well D-1 Reperforation On May 5, 1983, Well D-1 was reperforated w/ 4 HPF, 18° phasing, under drawdown at: B-2 11,320 - 11,406' DIL Tagged PBTD .@ 11,693' DIL Production before reperforating: (April 1983 averages) 1294 BFPD, 47.25% BS&W, 683 BOPD,_~I BWPD. Production after reperforating: 4200 BFPD, 72.00% BS&W, 1176 BOPD, 3024 BWPD. · MAY .'3 *Marathon Oil Company Sub-operator Alaska 0il & Gas C0ns~ (;0mr~issi0r¢¢ , Anchor'age,,? ..... ¢'"'"";~ 7,,,,/~, .,? 14. I hereby,,c&rtif,¢~t the foregoing is true and correct to the best of my knowledge. Signed:k' ...... Title , The space below for Commission use Date Conditions of Approval, if any: Approved by COMMISSIONER By Order of the Commission Date Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate '~"r~ STATE OF ALASKA ( .... ALASKA IL AND GAS CONSERVATION COI¥1MISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL OTHER 2. Name of Operator 7. Permit No. Union Oil Company of California * 67-80 3. Address 8. APl Number P.O. Box 6247 Anchorage AK 99502 50- 733-20086 4. Location of Well 9. t~it or. Lease Name Surface- 'lracL~ng Bay Unit Leg A- 2, cond #1, Dolly Varden Platform 755' FSL, 1126' FWL, Sec. 6-8N-13W-SM 5. Elevation in feet (indicate KB. DF etc.) 106 ' KB above MSL ' 10. Well Number 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). Reperforate TBU Well D-1 It is Marathon's intention to reperforate the well with 2 5/8" guns at 4 HPF, offset 15©, Under drawdown at: B-2 11',320' - 11,406' DIL. January, 1983, production averaged- 2255 BFPD, 49.50% WC, 1139 BOPD, 1116 BWPD. Work Beportecl -3 * Marathon 9il Company - Sub-operator 14. I hereJ~ertify that the_forego)lng is true~ Signed~ _ 7diti°ns °f Appr°val' if any: // Approved by ~nd correct to the best of my knowledge. Approved Copy . Returned By Order of COMMISSIONER the Commission ,/ Form 10403 Rev. 7-1430 Submit "Intentions" in 'l'ripli.cate and "Subsequent Reports" in I~uplicate. STATE OF ALASKA ,.v~ISSION ALASKA ,-.tN D GAS CONSERVATION CO SU__N___D. RY_ N_OTICES AND REPORTS ON WELLS DRILLING WELL I-] COMPLETED WELL [~f/ OTH~-~' 1~ 2. Name of Operator Union Oil Company of ~alifornia* 7. Permit No. 67-80 3. Address 8. APl Number P. O. Box 6247, Anchorage AK 99507 5o-733-20086 4. Location of Well Surface' Leg A-2, Cond #1, Dolly Varden Platform 755.3' FSL, 1125.5' FWL, Sec 6-8N-13W-SM 6. Lease Designation and Serial No. ADL-17594 5. Elevation in feet (indicate KB, DF, etc.) _ KB 106.2' abov~ Mb~ 12. 9. Unit or Lease Name Trading Bay Unit 10. Well Number D-1 11. Field and Pool McArthur River Field Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations [~ Altering Casing [] Stimulate [] Abandon [] Stimulation [] Abandonment [] Repair Well [] Change Plans [] Repairs Made [] Other [] Pull Tubing [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). On 4/21/82 Bench 4 was reperforated under drawdown with 2-1/8" perf guns, 0° phasing, 4 HPF, at the following intervals' 11,515'-11,560' DIL 11,575'-11,605' DIL 11,610'-11,670' DIL Production prior to reperforation 1440 BFPD, 36% WC, 922 BOPD, 518 BWPD Production after reperforation 5339 BFPD, 61% WC, 2082 BOPD, 3257 BWPD Benches 1 and 2 were not reperforated at this time. * Marathon Oil Company - Sub-Operator ' 0.2982 ,Naska Oil & Gas Cons. C°iu~ission AnChorage 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ¢'_'~ ....... Title The space below for Commission use 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 Perm No. P--4 1RZEV. 9-30-61 STATE OF ALASKA SUBMIT IN DIKPLICATE OIL AND GAS CONSERVATION COMMITTEE A~ONT'HLY RE:PORT OF DRILLING AND WORKOVER OPERATIONS 2. N~E OF OPERATOR Union Oil Company of California* 3. ADDRESS OF OPEl:CATeR 2805 Denali Street, Anchoraqe, Alaska 99509 4. LOCATION O,F WELL Surface' 755.3' Nc~Jand 1125.5' E of SW corner Sec. 6-8N-13W-SM Bottom Hole' 882.7' N and 3620.08' E of SW corner Sec. 32-9N-13W-SM 5. AP1 NU.%IER.ICAL CODE 50-133-20086 6. LF_~.SE DESIGNATION AND SE1RIAL NO. ADL 17594 A887 7. IF INDIAN. ALOTTEE OR TRIBE NAME 8.L.'-/X'IT,F.~'%¢ OR LEASE NAAIE Tradinq Bay Unit 9. WELL NO. D-1 {34-32) 10. FIEI.~D A_N'D POOL, OR WILDCAT .... McArthur River Hemlock Il. SEC.. T., R., M., (BO/TO.R{ HOL,E OBJECTIVE ) Sec. 32-9N-13W-SM lg. P~'2R/Vl IT 67-80 12. REPORT TOTAL DEPTH AT END OF MONTH, CPIANGES IN HOLE SI~,E, CASING A_ND CE1VIENTING JOBS INCLUDING DEPTH SET AN]i) VOLU1VIES USED, PE1RFORATIONS. TESTS A_NZD RESULTS. FISPIING JOBS, jLI'NK IN HOLE A_ND SIDE-TI:LACKED HOLE AND ANY OTHER SIGNIFICANT CPI~NGF-.S IN HOLy CONDITIONS. T.rading Ba7 Unit State D-l, February,.. 1968 - Page 2 hole. Ran 1.5" overshot and recovered fish. Total Depth- 12,071' M.D. and 9782' TVD permanent packer at 11,149' (tubing measurements). Ball valve landing nipples at 344' in long string and at 312' in short string. Removed'BOP equipment and installed Xmas tree. Retrieved ball valve dummies from both strings and circulated through 1/4" control lines. Set dual packer at 9502' with 3500#. Ran Lane-Wells perforating gun but could not get below ll,156'. Ran 1.90" OD swage on wireline tools. Jarred through restriction at ll,156'. Ran 2.30" OD swage but could not get through restriction. Ran 2.10" OD sWage .and jarred through restriction. Ran 2.30" swage but could not jar through restriction.<~ Wireline tools backed off while coming out of hole leaving 18.36' of. fish Now running 2.20" OD swage, * Marathon Oil Company, Sub-Operator, Dolly Varden Platform 14. ! hereby certify r ,s requ,red for each ca,endar month, regard,ess of the status o, o~at~sOn N01E--RepoKt th)s form on with the Division of Mines & Minerals by the 15th of the succeeding month, unless othe~ise directed? DIVISION OF MINES & M)NERALS ANCHORAGE Form No. !R,]D'V". 9-30-67 STATE O'F ALASKA SUB1VZIT IN DEPLTCATE OIL AND GAS CONSERVATION COMMI1-FEE MONTHLY REPORT OF DRILLING AND WORKOVER OPE:RATIONS -5.API NUA~ERICAL CODE 50-]33-20086 6. LF_~,SE DESIGNATION AND SEIKIAL NO. ADL 17594 A 887 1. 7. IF INDIAN, ..%LOTTEE OR TRIBE 0IL ~ GAS [] 2. NA/~IE OF OPERJkTOR 8, LTNIT FAI~%{ OR LEASE NLAAIE Union Oil Company of California * Trad'ing Bay Unit 3. ADDRESS OF OPEI:~TOR 9. %VELL 2805 Denali Street, Anchorage, Alaska 99503 D-1 (34-32) 10. FIELD A-ND POOL. OR WILDCAT McArthur River Hemlock 4.LOCATION O'F WELL Surface' 755.3' N and ],]25.5' E of SW corner Sec 6-8N-I 3W-SM At Proposed Prod. Zone' 660' N and 1,980' W of SE corner Sec 32-9N-13W-SM 11, SEC,, T., 1~,, AZ., (BOT'FOM HOLE OBJECTIVE) Sec 32-9N-13W-SM 13, REPORT TOTAL DEPTH A.T END OF MONTH, CHANGES IN I-IOLE SI~,E, CASING A/ND CE1VIEATTING JOBS INCLUDING DEPTH SET AND VOLU1VIES USED, PERFORATIONS, TESTS A/ND RESULTS, FISHING JOES, JLr~K IJq HOLE A.ND SIDE-TI~ACKED HOLE AND ANY OTI-IER SIGNIFICANT CI-IA/~GF~ IN HOL$ CONT)ITIONS. T_r_ad~ing Bay Unit State D-l, Januar.~, 1968 1/1 Drilled float collar and tested BOP equipment and casing with 3,000# for 15 minutes, OK. Drilled shoe. 1/2-1/27 Drilled 12-l/4" hole to 9,700'. 1/28-1/30 Ran Lane-Wells Dual Induction, Acoustic, Gamma Ray, Density, and Dipmeter logs. Shot and recovered 9 sidewall samples. Circulated and conditioned mud. 1/31 TD 9,700'. Ran 230 its 9-5/8" 40#, 43.5#, 47#, N-80 and R-1lO Buttress casing DV collar at 5,856', float collar at 9,645', and shoe at 9,690'. Preparing to cement casing. Last Directional Survey-. 9,700' MD, 7,937' TVD, N4388.72', E2297.71', 4,945.38' from Surface location. * Marathon Oil Company - Sub-operator - Dolly Varden Platform RECEIVED FEB 6 1968 DIVISION OF MINES & MINERALS ANCHORAGE 14, I hereby cer~i£y, that th~ ~oregoi,ng is true q~ad correct ' STGN~D__~ '-,/J ~/)//C//)/Zf'L~/LA/',,---~ W~T~Dis~. Drilling Superintended,% 2-5-6,8 , . H .~.Mr, M~hmn ii NOTE--Report on this form is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the Division of Mines & Minerals by the 15th of the succeeding month, unless otherwise directed. Union Oil Companyj~ alifornia 507 W. Northern Lights Blvd., Anchorage, Alaska 99503 ":' Telephone (907) 277-1401 ¢':: union January 15, 1968 Mr. T.R. Marshall, Jr. State Petroleum Supervisor Division of Mines ~ Minerals~ 5001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Marshall' Revised Locations- Trading Bay Unit State D1 ~.T.rading Bay Unit State D2 Enclosed for your information is a copy of a letter from Marathon Oil Company, Operator of the subject wells, and a copy of the revised plat. The revised locations are as follows- Trading Bay Unit State D1- 755' from the South line and 1,125' from the West line of Section 6, T8N, RISW, S.M. Trading Bay Unit State D2: 685' from the South line and 1,212' from -- the West line of Section 6, TSN, R1SW, S.M. cc' Mr. W.J. Linton U.S.G.S. Trading Bay Unit Participants Enclosures (2) Very truly yours, q H.D. McMahan Dril ling Superintendent FORM 401-ANC-W (8/67) Form REV. 9-30~67 Submit "Intentions" in Triplicate & "Subsequent Reports" in Duplicate 'i'~'; STATE O,F ALASKA OIL AND GAS CONSERVATION ,COMMITTEE SUNDRY NOTICES AND REPORTS O,N WELLS (Do not use this form for proposals to drill or to deepen or plug back to a diffierent reservoir. Use "APPLICATION FOR PEi~/IIT--" for such proposals.) 1. WELL WELL OTHER 2. NAME OF,gPI~RATO~ . union ull Company of California* 2805 Denali Street, Anchorage, Alaska 99501 4. LOCATION. O,F WELL Atsurface 755.3' N and 1125.5' E from SW corner Sec. 6, 8N, 13W, SM At Proposed Prod. Zone: 660' N and 1980' W from SE corner- Sec 32, 9N, 13W, SM 5. API NU/VLE~IC~ CODE 50-] 33-20086 6. LEASE DES/GNkTION A.ND SERr3kL NO. ADL 17594 A 887 7. IF INDIA.N, ALLOTTEE OR TRIBE NAME 8. UNIT, FAi{1VI OR LEASE NAME Trading Bay Unit 9. ~V]~IE,L NO. D-I (34-32) 10. FIELD A~ND POOL, OR WILDCAT McArthur River Hemlock 11. SEC., T., R., M., (BOTTOM HOLE OBJECTIVE) Sec 32, 9N-13W SM 13. ELEVATIONS (Show whether DF, RT, Gl{, etc. 12. PER1VIIT 1~O. 116' RT MLLW 67-80 C~ck Appropriate I~x To I~nd, i'c;a,te Nlat'ure of N~ti'c'e, Re ~,ort, or 'Other 'Date NOTICE OF INTENTION TO: TEST WATER SHUT-OFF I [ PULL OR ALTER CASING FRACTURE TREAT [ [ MULTIPLE COMPI,ETE SHOOT OR ACIDIZE ~ ABANDONs REPAIR WELL CHANGE PLANS SUBSEQUENT REPORT OF: WATER SIIUT-OFF REPAIRING WELL FRACTURE TREATMENT ALTERING CASING SHOOTING OR ACIDIZING ABANDONMEN'Ts (Other) (NOTE: Report results of multiple completion on Well (Other)Corrected Surface Location 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. An error has been detected in the original jsu~vey calculations from which the surface location of the above well was derived. The surface location has been corrected as fol 1 ows: Original location in error: 754.7' N and 1132.1' E from SW Corner- Sec. 6-8N-13W-SM New correct location: 755.3' N and 1125.5' E from SW Corner- Sec. 6-8N-13W-SM Marathon Oil Company - Sub-operator - Dolly Varden Platform 16. I hereby certffy, tbcat the foregoing is tru~/ and correct SIGNED ..... ' H.D. McMahan TITLE Dist. Drilling Superintenden~aTE 1-17-68 (This space for State office use)/ . ~ ~ .,/ / ../ ~."" .. ,/.~9, APPROVED BY /~,/ /". ~" r.... :.?"~ ..... :-<:~ .... '".'-.~ ......... CONDITIONS O~.~PPROVAL, IF A~: ... TITLE See instructions On Reverse S,ide U-M / / UNION-MAR. / DOLLY VA R D,~N .32 0-1 TMD 11885' (~ TVD 9780'// / / ADL-,[,T.5,9'q' ./ ,?' / / / 1 / / / / / / / ! / / \ \ \ \ G-3 _ T, 9N, RI3W _ __ -- T8N, RI3W U-M ADL 18729 PPSS ADL 17579 I I I 34 I U-M ADL 18730 TD'"'~T'~°"-°"'or 'o~ - o?..o~ 4 L II J7 unl( n WELL LOCATION MAP MARATHON- SUB-OPERATOR TRADING BAY STATE UNIT D-I (34-32) lATE' NOV. 1967 SCALE ' I"= 2000' MARATHON OIL COMPANY PI:::IODUOTION - UNITEE) STATES /~ND CANAl-IA 1~. 0. BOX 731 "l" 9TI:=IEEI=T ~NCH O1::1/~ G E, ~l/~9 K~ 99501 January 12, 1968 Mr. H. D. McMahan Union Oil Company of California 507 Northern Lights Boulevard Anchorage, A1 aska Dear Mr. McMahan: In October, 1.967 you were mailed a drawing of the wellhead plan for the Dolly Varden Platform prepared by F.M. Lindsey & Asso- ciates, dated August 18, 1967, and identified by No. C.C. 11265 in the lower right hand corner. An error has been found in the drawing which was sent you and a new plat has been prepared by F. M. Lindsey with the same title but dated January 8, 1968. Two copies of the revised wellhead plan are enclosed and I re- quest that you destroy the old copies. Please revise Whatever records have been made showing the location of ¥Iell D-1 in Pile 1 of Leg A-2 and l,lell D-2 in Pile 7 of Leg B,1. The coordinates of these two wells were misrepresented on the original plat. All future well locations for the Dolly.Varden Platform will be based on the revised plat. TJC/ahe Yours very truly, I. d. Challoner Di strict Operations Manager Enclosures-2 JAN 5 1968 I'-I. I). We, U-M UNION - MAR. / DOLLY VA R D/E"N D-I 1750'-- TMD 11885' TVD 9780~// / / - ADL- 17594 / , ,..~ / / / / / / / / \ \ \ \ \ 13-3 T_9_N, R ~3W . T8N, RI3W U-M ADL 18729 PPSS ADL 17579 J¥ I II I 34 I , , , I,U-M ADL 18730 -o~. - (>,~ '04 unlen WELL LOCATION MAP MARATHON- SUB-OPERATOR TRADING BAY' STATE UNIT D-I (34-32) lATE' NOV. t967 SCALE' I": 2000' i.. Forra P--1 R.E~. 9-30-67 SUBMIT IN (Other instructioh~ reverse side) STATE O,F ALASKA OIL AND. GAS CONSERVATION ,COMMITTEE' APPLICATION FOR PERMIT TO DRILL, DEEPEN, OR PLUG BACK IlL TYPE OF WORK DRILL [] DEEPEN J--J PLUG BACK J--J b. TYPE OF WELL OIL ~ OA~ ~-~ SINGLE ~ MULTIPLE ~_~ WELL WELL OTHER ZONE ZONE 2. NAME OF OPE2L~TOR Union 0il Company of California * 3. ADDRESS OF OPEiRATOR 2805 Denali Street, Anchorage, Alaska 4. LOCATION OF WELL AZ surface £E AP1 ~0-133-20068 _ 6. LEASE DESIGNATION AND SERIAL NO. ADL 17594 ?. IF INDIAN. A_Li~TTEE OR TRIBE NAI~E 8. UNIT, FARM OR LEASE NAiViE 14. 99505 Trading Bay Unit 9. WELL NO. D-1 (34-32) 10. FIELD AND POOL, OR WILDCAT McArthur River Hemlock 754.7' N and 1132.1' E from SW corner of Sec 6, T8N, R13W, S.M. At proposed prod. zone 660' N and 1980' W from SE corner of Sec 52, T9N, R!iW, S.g, DISTANCE IN MILES AND DIRECTION Fl{OM NEAREST TOWN OR.POST OFFICE* 21 miles northwest of Kenai, Alaska In. SEC.-, T., R., M., (BOTTO~ HOLE OBJECTIVE) BOND INFOR/VIATION: USA TYPE NATIONWIDBurety and/or No. No. 554-979-1 15. DISTANCE FROM PROPOSED* LOCATION TO NEARE:ST PROPERTY OR LEASE LINE, FT. (Also to nearest drig, unit, if any) The Ohio Casualty Insurance Company 660' 18. DISTANCE FROM PROPOSED LO.CATIO'N~ TO NEAREST WELL DRILLING, COMPLETED, OR APPLIED FOR, FT. 5700 feet from Trading Bay Uni;t G-3 21. ELEVATIONS (Show whether DF, RT, C-R, etch 116' R.T., M.L.L.W. t16. NO. OF ACRES IN LEASE 5116,.00 !9. PRopOSED DEPTH" 11,885MD, 9780 VD PXO'POSED CASING AND CEMENTING PROGRAM" 23. Sec 32, T9N, R13W, S.M. 12. ~ou:~' $150 , 000 , 00 , ~. No. ACRES ASSIGNED' TO TI-IfS WELL 20. ROTARY OR CABLE TOOLS Rotary 22. APPR, OX., D~E ',WORK WILL START* December 15, 1967 ,. SIZE OF HOLE [' SIZE OF CASING 12¼"-26" 20 12~"- 17½" 12¼" 8½" lS-S/8 , 9-5/s 7" liner 94. I I H'-40 61.,. I j_ss 40,45.5,47. N-80 29 N-80 SETTING DEPX~ · 650 ,2500 9000 11,885 QU~ANTITY OF CEMEN'2 Blowout Preventer Program: Install and test 20"-2000# H w/2000# after setting 20" 94# casing. Install and test Cameron type "U"'d0uble gate preventer, 5000# Kill-linei with 3000# after setting 13-3/8":61# casing. Install an 5000# Cameron type "U'" double gate preventer, 5000# Kill 5000# after setting 9-5/8" 47# casing. Use same BOP's f, Bottom Hole location: 1100' N & 1750' W from SE corner rdril, Kill-line and choke manifold 13-5/8"-5000# Hydril, 13-5/8"'5000# and S000# flanged choke manifold ~ test 13-S/8'"-S000# Hydril, 13-S/8'w- line and S000# choke manifold with .r setting of 7" liner. Sec 32, TgN, R13W, S.M. * Marathon Oil Company, Suboperator Dolly Varden Platform IAI ABOVE SPACE DESCRIBE PI%OlmOSED PI%OG.RA1Vi: If proposal is to deepen or plug l]~ac'~., giye .data o.n pre:sen~ produ.ctive zone and proposed new productive zolie. If pro,posal is to drill or deepen directLonally, give pertinent data on $~bsur£ace ~ocations and measure4 and true vertical depths. Give blo.wout preventer progra.rn. 24. I hJi~Ylce:r~ t3hat J~l~oregoing is ~r~nc~ C~rrec% DA~ November 2;0"; !967_ TI~ Landman (This space for State office use) SAMPLES AND CORE CHIPS R,EQUIi~ED , []YES []N'O', ' ' " DIRECTIONAL SURVEY REQUIRED [] YES . CONDITIONS OF APPROVAL, IF ~ANY: ', OTHER REQUIREME~. TS: A.P.I. NTI1VIEI:~CA.L CODE APPROVAL DATE THOMAS R. MARSHALl, ~xecufive Secrelar~ ~n~e~atioa ~mmi~ ~,:~, ,,:~' ~ ~:',~ ...... :t,','~, ,~:,:' --t FORM SA- I B ~ 25.5M 8/67 MEMORANDUM TO: I-- State of Alaska I)IV~SXOBI OF ~]~II]~S AI~ FROM: Thamm Ilo ~,1~ DATE : SUBJECT: Deeesber 50 1967 ~uion oll Co. of Re: Trmiing nay Unit Union oti Co. of Ca/i£., Operaco~ ~ O~ Com~an~ o:f C~li~ornia ,d~l the ~efereaeed ve~. ~ell ,sauple aud ~ore chips are ,r~qut~ed. ~ :R. liarshaLl.., · etzolemu ~upervis~