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100-148
Reviewed By: P.I. 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Hunt 8/2/2024 2024-0802_Suspend_SRU_331-27_photos_jh Page 2 of 2 1. Operations Abandon Plug Perforations Fracture Stimulate Pull Tubing Operations shutdown Performed: Suspend Perforate Other Stimulate Alter Casing Change Approved Program Plug for Redrill Perforate New Pool Repair Well Re-enter Susp Well Other: Suspended Well Inspection Development Exploratory Stratigraphic Service 6. API Number: 7. Property Designation (Lease Number):8. Well Name and Number: 9. Logs (List logs and submit electronic data per 20AAC25.071):10. Field/Pool(s): 11. Present Well Condition Summary: Total Depth measured 12,046 feet 4,306 & 11,077 feet true vertical 12,046 feet N/A feet Effective Depth measured 4,306 feet N/A feet true vertical 4,306 feet N/A feet Perforation depth Measured depth See Attached Schematic True Vertical depth See Attached Schematic Tubing (size, grade, measured and true vertical depth)3-1/2" 9.3# / L-80 10,701' MD 10,701' 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): Treatment descriptions including volumes used and final pressure:N/A 13. Prior to well operation: Subsequent to operation: 15. Well Class after work: Daily Report of Well Operations Exploratory Development Service Stratigraphic Copies of Logs and Surveys Run 16. Well Status after work: Oil Gas WDSPL Electronic Fracture Stimulation Data GSTOR GINJ SUSP SPLUG Sundry Number or N/A if C.O. Exempt: Taylor Wellman 777-8449 Contact Name:Ted Kramer Authorized Title:Operations Manager Contact Email: Contact Phone:777-8420 WINJ WAG 0 Water-Bbl MD 22' 1,490' 0 Oil-Bbl measured true vertical Packer 7:00 11,620'11,620' measured 3800 Centerpoint Dr Suite 1400 Anchorage, AK 99503 Swanson River / Hemlock OilN/A measured TVD Tubing Pressure 00 Swanson River Unit (SRU) 331-27 N/A FEDA028406 Plugs Junk STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 100-148 50-133-10156-00-00 4. Well Class Before Work:5. Permit to Drill Number: 3. Address: 2. Operator Name:Hilcorp Alaska, LLC 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. N/A 0 Size 14. Attachments (required per 20 AAC 25.070, 25.071, & 25.283) 0 Gas-Mcf 0 Authorized Signature with date: Authorized Name: 0 Casing Pressure Liner 0 0 Representative Daily Average Production or Injection Data 22' 1,490' 11,620' Conductor Surface Intermediate Production 7,240psi Casing Structural 20" 13-3/8" Length 2,730psi Collapse 853psi tkramer@hilcorp.com Senior Engineer:Senior Res. Engineer: Burst 604psi 22' 1,490' t Fra O 6. A G L PG , R Form 10-404 Revised 3/2020 Submit Within 30 days of Operations By Samantha Carlisle at 9:29 am, Sep 28, 2020 Digitally signed by Taylor Wellman DN: cn=Taylor Wellman, ou=Users Date: 2020.09.26 14:21:10 -08'00' Taylor Wellman RBDMS HEW 9/30/2020 Suspended Well Inspection DSR-9/28/2020gls 10/22/20 SUSP SFD 9/29/2020 KEN June 2020 Suspended Well Inspection Data Well: Swanson River Unit 331-27 Surface Location: 40’ FNL, 1,730’ FEL, Sec. 27, T8N, R9W, S.M. Permit to Drill: 100-148 API: 50-133-10156-00-00 AOGCC Inspection Date: 09/04/20 AOGCC Inspector: Lou Laubenstein Hilcorp Representative: Jake Paulk Size Pressure (psi) Tubing 0 Casing 25 0 *Note: Wellhead pressures to be recorded monthly at minimum. Other Notes: x Condition of Wellhead: Good x Condition of Surrounding Surface Location: Good x Follow Up Actions needed: None Attachments: x Current Well Schematic x Picture(s) x Plat - 1/4mile radius of wellbore Note: 7" casing last tested in 2014 (gls ) Downhole Revised: 9/16/14 Revised By DMA 09-18-20 ACTUAL SCHEMATIC Swanson River Unit Well: SRU 331-27 Completion Ran: 9/16/2014 PTD: 100-148 API: 50-133-10156-00 PBTD = 4,306’ MD / 4,306’ TVD TD = 12,046’ MD / 12,046’ TVD RKB: 272’ / GL: 257’ AMSL KB – THF: 15.0’ H-4 Casing Detail Size Type Wt Grade ID Top Btm Hole Cmt Cmt Top 20” Conductor - - - Surf 22’ - unknown Surf. 13-д” Surface 54.5 J-55 12.615” Surf 1,490’ 18-з” 1,500 sx Surf. 1,497’ 7” Prod Csg 29 P-110 6.184” Surf 1,027’ 12-¼” 2,725’ 1,000 sx 9,140’ CBL 7” 29 N-80 6.184” 1,027’ 2,172’ 10-з” 11,659’ 7" 26 N-80 6.276” 2,172’ 8,192’ 7” 29 N-80 6.184” 8,192’ 10,695’ 7” 29 P-110 6.184” 10,695’ 11,620’ Tubing Detail Cplg OD 3.5” EUE 8RD 9.3 L-80 2.992” 4,311’ 10,701’ 4.500” Jewelry Detail No. Depth ID OD Item 1 1,023’ 2.992” 3.500” 3-1/2” EUE 8RD Kill String (33 jts) 2 4,306’ - - Cement Retainer, Squeeze 90 bbl 15.8 ppg cement below 3 5,853’ 2.992” 5.313” Gaslift Mandrel, Camco MM, Live Valve 4 7,974’ 2.992” 5.313” Gaslift Mandrel, Camco MM, Live Valve 5 10,600’ 2.992” 5.313” Gaslift Mandrel, Camco MM, No Valve 6 10,701’ - 4.000” Top of ESP, Discharge Head 7 10,788’ - 4.000” ESP Intake 8 10,788’ 4.950” 5.500” ESP Shroud (31’ of 5-1/2” 15.5# Casing) 9 10,820’ - 5.520” Base of ESP, 456 series Motor / 400 series Pumps 10 11,077’ - - Lost 7 ea ¾” SS bands (5.8” GR tagged on bottom 11/16/13) 11 11,077’ - - Cement Retainer, Capped w/ 10 sx cement Perforation History Date Zone Top(MD) Btm(MD) Top(MD) Btm(MD) Amt spf Comments 12/11/58 WSO 10,795' 10,796' 10,795' 10,796' 1' 4 12/14/58 H-4 10,804' 10,836' 10,804' 10,836' 32' 4 Squeezed 12/14/58 H-5 10,849' 10,878' 10,849' 10,878' 29' 4 Squeezed 12/11/58 WSO 10,880' 10,881' 10,880' 10,881' 1' 4 8/31/2012 H-6 10,906’ 10,916’ 10,906’ 10,916’ 10’ 6 2.5” Owen 8/31/2012 H-7 10,926’ 10,948’ 10,926’ 10,948’ 22’ 6 2.5” Owen 12/09/58 Hemlock 11,038' 11,060' 11,038' 11,060' 22' 4 Open 8/31/2012 H-10 11,050’ 11,076’ 11,050’ 11,076’ 26’ 6 2.5” Owen 12/07/58 Hemlock 11,185' 11,195' 11,185' 11,195' 10' 4 Isolated 20” 22’ 13-3/8” 1,490’ 7” 11,620’ CBL TOC 9,140’ WSO WSO Hemlock Hemlock H-5 H-6 H-7 H-10 11 Milled K retainer to 11,077’ 9 3 4 5 6 Cable/Clamp/Band Detail 10,800’ – 10,820’ - 8 ea 4560 Cannon Clamps (Across Motor Only) 10,701’ – 10,800’ - 18 ea 4010 Cannon Clamps (Across Pumps/Poseidon Gas Handler/Protector) 10,671’ – 10,701’ - 9 ea ¾” SS bands (all on 1st joint above discharge head) 0’ – 10,671’ - 3 ea ¾” SS bands per tubing joint (additional 1 ea for flatpack every other joint) (Total of 1184 SS bands) 0’ – 10,680’ - 1 ea Reda #1 Round ESP Cable (Splices at approx. 35’, 159’, 5,912’, and 10,680’) 10,680’ – 10,800’ - 1 ea MLE Flat Cable (Splice depth at approx.. 10,680’) 0’ – 10,702’ - 1 ea Dual Flatpack Encapsulated Control Lines (2 ea Chem Inj) 10,702’ – 10,820’ - 1 ea Tri Flatpack Encapsulated Control Lines (2 ea Chem Inj, 1 ea Phoenix) 7 8 10 Suspect Downhole Cable Failure @ Unknown depth Obstruction @ 7,210’ SLM 2.50” LIB Tag Pump @ 10,720’ SLM 2.35” GR 5/31/14 Stuck @ unknown depth 2 1 Kill Fluid 8.5 ppg Lease Water 7” Csg Tested to 1,500 psi 9/15/14 Tested to 1,500 psi 9/15/14 P ' Y Q ! ! !! ' Y QQ Y SRU 331-27 S008N009W SWANSON RIVER FIELD SRU_23-22 SRU_21-27 SRU_331-27 SRU_32-27SRU_21-27SRU_23-22KGSF 3SRU 21-27 Pad SRU 32-27 Pad SRU 331-27 Pad Sec. 22 Sec. 27 0 250 500 Feet Alaska State Plane Zone 4, NAD27 ¯ Legend Quarter-Mile Radius around Well Bore Oil and Gas Unit Boundary Map Date: 6/22/2020 SWANSON RIVER SRU 331-27 Suspended Well ! ! ! !! ! Location Map Overview Coo k I nl et Kenai Homer Tyonek SewardNinilchik Anchorage HAK Petra Well Symbol'Oil Q P&A Y Suspended Suspended WellInspection --'-ew Report |nspectNo: susLOL200908105227 Date Inspected: 9/4/2020 ' Inspector: Lou Laubenstein' Type oFInspection Well Name: SVVANSUN K|VUNIT 331,27 Permit Number: 1001480 ' Suspension Approval: � Sundry ' # 314-416 ' � Suspension Date: � 9/16/2014 -- LncatiunVehfied? b11 |fVerified, How? GPS Offshore? U Subsequent Date AOG[CNotified: 8/25/2020 Operator: Hi|mrp Alaska, LLC Operator Rep: Daniel Faulk � Wellbore Diagram Avail 7 Photos Taken? WellWellPressures (ps|): Tubing: O . Fluid inCellar? k � |A: IS 8PV|nstaUed? El Ui%: 0 ' VR Plug(s) Installed? [] Wellhead Condition The Wellhead was in good condition with no signs of leakage or issues. Condition of[eUar The cellar ismade from what looks tobeWood and concrete, itisntinthe best condition. Some water was inthe cellar but itlooked clean. Surrounding Surfaoe{ondition ~ The pad surrounding the wellhead looked good and was free of any debis or leakage. Comments ',�upem)sorComments � Photos (3) attached Monday, October 12'2OlO O O N N LO O co O O O O N J O J U) U O Q U) O U �0 d Q C O (B J J O U Q c U U O Q T O N O NO a_ O M M x o � C) m N P. 0 b 0 Y O N M M STATE OF ALASKA AIDA OIL AND GAS CONSERVATION COMOSION REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon Li Plug Perforations ❑ Fracture Stimulate ❑ Pull Tubing❑ Operations shutdown ❑ Performed: Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing ❑ Change Approved Program ❑ Plug for Redrill ❑ erforate New Pool ❑ Repair Well ❑ Re-enter Susp Well❑ Other: Suspended Well Inspection E 2.Operator 4.Well Class Before Work: 5.Permit to Drill Number: Name: Hilcorp Alaska,LLC Development ❑✓ Exploratory ❑ . 100-148 3.Address: 3800 Centerpoint Drive,Suite 1400 Stratigraphic❑ Service ❑ 6.API Number: Anchorage,AK 99503 e 50-133-10156-00-00 7. Property Designation(Lease Number): 8.Well Name and Number: • FEDA028406 • Swanson River Unit(SRU)331-27 9. Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): N/A ' Swanson River/Hemlock Oil 11. Present Well Condition Summary: `{/�E D Total Depth measured , 12,046 feet Plugs measured 4,306&11,077 el e C E 1 true vertical + 12,046 feet Junk measured N/A feet ,EP 1 1 2015 Effective Depth measured 11,077 feet Packer measured N/A feet OGCCtrue vertical 11,077 feet true vertical N/A feet Casing Length Size MD TVD Burst Collapse Structural Conductor 22' 20" 22' 22' Surface 1,490' 13-3/8" 1,490' 1,490' 2,730 psi 853 psi Intermediate Production 11,620' 7" 11,620' 11,620' 604 psi 7,240 psi Liner Perforation depth Measured depth See Attached Schematic %A��ED DEC 1 5 2015, True Vertical depth See Attached Schematic %M Tubing(size,grade,measured and true vertical depth) 3-1/2" 9.3#/L-80 10,701'MD 10,701'TVD Packers and SSSV(type,measured and true vertical depth) N/A N/A N/A N/A X12.Stimulation or cement squeeze summary: N/A Intervals treated(measured): N/A Treatment descriptions including volumes used and final pressure: N/A 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 0 0 0 0 Subsequent to operation: 0 0 0 0 0 14.Attachments(required per 20 AAC 25.070.25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations ❑ Exploratory Development El . Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run Li 16.Well Status after work: Oil ❑ Gas ❑ WDSPL❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ - SUSP❑ SPLUG❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: N/A Contact Joe Kaiser Email jkaiser@hilcorp.com Printed Name /� Joe Kaiser Title Operations Engineer Signature 1�1 `„g/ c-ytsc- Phone 907-777-8393 Date 7 j 1 ( .1S Form 10-404 Revised 5/2015 RBDM SCP 1 5 2015 Submit Original Only c(-(1.1 )f 9/T�/� • • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Suspended Well Inspection Report Date Inspected: 08/26/15 Inspector: Jeff Jones Operator: Hilcorp Alaska Well Name: Swanson River Unit 331-27 Oper. Rep: Rick Musgrove PTD No.: 100-148 Oper. Phone: 907-283-2551 Location Verified? Yes Oper.Email: rmusgrove@hilcorp.com If Verified,How? Other(specify in comments) Onshore/Offshore: Onshore Suspension Date: 09/16/14 Date AOGCC Notified: 08/04/15 Sundry No.: 314-416 Type of Inspection: Initial Wellbore Diagram Avail.? Yes Well Pressures(psi): Tubing 0 Photos Taken? Yes IA 10 OA 10 Condition of Wellhead: Good,no visible leaks.All vavles and gauges operable. Condition of Surrounding Surface Location: Good condition,gravel pad,clean. Follow Up Actions Needed: None Comments: Location verified by wellsign. Lat. 60.7626713792132 Long. -150.831540055462 Attachments: REVIEWED BY: Insp.Supry Comm PLB 12/2014 SRU 331-27 Suspended Well Inspection Form H . • Swanson Unit Well: SRU 331-27 ACTUAL SCHEMATIC Completion River Ran: 9/16/2014 Ililcorp Alaska,LL(: PTD: 100-148 API: 50-133-10156-00 RKB:272'/GL:257'AMSL Casing Detail KB-THF:15.0' Size Type Wt Grade ID Top Btm Hole Cmt Cmt Top 20" Conductor - - - Surf 22' unknown Surf. 20' Exv,":41,4 18% 22' ' LI 13-%s" Surface 54.5 J-55 12.615" Surf 1,490' 1,500 sx Surf. /.,,,,, 1,497' 1 7" 29 P-110 6.184" Surf 1,027' 12 Kill Fluid 2,725' $,9 8.5 ppg 7" 29 N-80 6.184" 1,027' 2,172' 10-3/4" 13-3/8" '`s Lease Water 44`1 Prod Csg 11,659' 1,000 sx 9,140'CBL 1,490' � 7" 26 N-80 6.276" 2,172' 8,192' J 2 r Csg 7" 29 N-80 6.184" 8,192' 10,695' iik Tested to 7" 29 P-110 6.184" 10,695' 11,620' Stuck@ 1,500 psi Tubing Detail CplgOD unknown 9/15/14 depth 3.5" EUE 8RD 9.3 L-80 2.992" 4,311' 10,701' 4.500" Suspect 3 Jewelry Detail Downhole No. Depth ID OD Item Cable 1 1,023' 2.992" 3.500" 3-1/2"EUE 8RD Kill String(33 jts) Failure @ Obstruction Unknown I @ 2 4,306' - - Cement Retainer,Squeeze 90 bbl 15.8 ppg cement below depth I 7,210'SLM 3 5,853' 2.992" 5.313" Gaslift Mandrel,Camco MM,Live Valve 1IS 4 2.50 LIB 4 7,974' 2.992" 5.313" Gaslift Mandrel,Camco MM,Live Valve CBL TOC 5 10,600' 2.992" 5.313" Gaslift Mandrel,Camco MM,No Valve 9,140' 6 10,701' - 4.000" Top of ESP,Discharge Head till 7 10,788' - 4.000" ESP Intake ( ill ' ' - 8 10,788' 4.950" 5.500" ESP Shroud(31'of 5-1/2"15.5#Casing) 9 10,820' - 5.520" Base of ESP,456 series Motor/400 series Pumps Tag Pump 10 11,077' - - Lost 7 ea%"SS bands(5.8"GR tagged on bottom 11/16/13) - @ ''''''4 6 11 11,077' - - Cement Retainer,Capped w/10 sx cement 10,720'SLM ''''11 2.35"GR 1 7 , Cable/Clamp/Band Detail 5/31/14 i il,1 10,800'-10,820' - 8 ea 4560 Cannon Clamps(Across Motor Only) 10,701'-10,800' - 18 ea 4010 Cannon Clamps(Across Pumps/Poseidon Gas Handler/Protector) 9 10,671'-10,701' - 9 ea%"SS bands(all on 15t joint above discharge head) 0'-10,671' - 3 ea%"SS bands per tubing joint(additional 1 ea for flatpack every other joint) - wso (Total of 1184 SS bands) 1= 0'-10,680' - 1 ea Reda#1 Round ESP Cable(Splices at approx.35',159', 5,912',and 10,680') H-4 10,680'-10,800' - 1 ea MLE Flat Cable(Splice depth at approx..10,680') 0'-10,702' - 1 ea Dual Flatpack Encapsulated Control Lines(2 ea Chem lnj) -I 10,702'-10,820' - 1 ea Tri Flatpack Encapsulated Control Lines(2 ea Chem Inj,1 ea Phoenix) "�1� H-5 Perforation History wso Date Zone Top(MD) Btm(MD) Top(MD) Btm(MD) Amt spf Comments ' H-6 12/11/58 WSO 10,795' 10,796' 10,795' 10,796' 1' 4 ' 12/14/58 H-4 10,804' 10,836' 10,804' 10,836' 32' 4 Squeezed Milled K H 7 12/14/58 H-5 10,849' 10,878' 10,849' 10,878' 29' 4 Squeezed retainer 12/11/58 WSO 10,880' 10,881' 10,880' 10,881' 1' 4 to H-10 11,077' 10 o Hemlock 8/31/2012 H-6 10,906' 10,916' 10,906' 10,916' 10' 6 2.5"Owen 11 `'`„ . .° 8/31/2012 H-7 10,926' 10,948' 10,926' 10,948' 22' 6 2.5"Owen 12/09/58 Hemlock 11,038' 11,060' 11,038' 11,060' 22' 4 Open 7„ _Hemlock 8/31/2012 H-10 11,050' 11,076' 11,050' 11,076' 26' 6 2.5"Owen 11,620' 1D=12,046' PB7D=11,077' 12/07/58 Hemlock 11,185' 11,195' 11,185' 11,195' 10' 4 Isolated Downhole Revised:9/16/14 Revised By STP 9/22/14 • • F,. t� + STs► '',..1+ , •3y c * �.41 r a E s SWANSON RIVER • Is API#50-133.10156-00-00 r `✓ PTD#100-148 LEASE#FED A028406 SURFACE LOCATION: I NVV1/4,NE114,SEC 17,TBN,R9W,SM 141110 . a- i. - '' '' ` ti fauftf��. � / 6 . rtr�Zr. t • S . ,:4'' ,' ' . - . . ,-,-,--.-,- ,....,. ..._.......4,-,..4.,:70.,-. 7 '"`,• ---' - , - ) _ Orkt • - - _ - . _ . ...- , ,.. .. 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":,... -/,', :..-,....';‘5--',''';.,,i."-''''',.:,,,,` ;;r.,..''.y.'..4W.,•' .,::_•;„Le,','-v---;•,,,,_,.._-:-'-''' '':4.-.14-Ar';';'"*.AP•441: -,:jiiit4.- "` ' ''''''''''' . ' ,,,,,-V..":. --..x.... -ft. .z...../...,,,t-e47.,.,:i.„:-•,A, 14.-s A,...,4*,..44,-.... , ,.. -' , . . - tr. ' , ' i'', % - 41',,,A, .. • ' . • ., .,40"..,;'. ' ' -,, ' N' . 'i f ' - ''t • ' ''' :.,, ,1, 1414.14.'- . ,(471i144.o'l ,4:: ' ",•-,-K,,',';''''1%,401-ei "4 - .'‘ of ... ... . , _ / :' .• , . 4," 1 r - -- 7 - 1 Tok•- ' ; ..-: , .k,.14,..,,'; -- _ . , ///// ! ,1/4 , I . 1 11\e '' s= / =, /iii / - ,. ! t. '6 i I . . '.%\ ` ' ' 1 • \ -, Lai A*0 jri / 1-'7 ,/ I I kill Sao asso f--- ,.., ,,, ,,, •,z4,,,w, .. ,,, .. , 0, 4,4.7IS4....4 VOOMINIIII' 1 ' III 11! - —'IlL" = • '''44'''-'tllt4' '' '1"'' ' ...''''',• •e.,;, :A,...4.1 3411? ''! , ' ., -,,, 4 Alt,,,, , , „., i,,,..)4,14.4,4_,\, 44p.* - ,- - • -, --- - -, ,,,r,t,.....,,--,\A.N.,,v , :-..,.- 2 1. , ,• , ,t,, ii,'‘,... ,-:',. '''''',:`,•V?-1.%. 2),.i ,,-,4',,.A.":.„..1,74,,•=.-.',,,..',;-,1..":''.44:A. &-•-1,%.,.Lh4,V.2,2-,,,i...,y.:i*t.,t.,.,,,,,` -e1_1-1iA1.1':.';St:*:r,:,--,''4,-''if'i,''r'-'-.4q,.,..t„4',V,,4T1:v-1:`:,,y',:',':.T,',,I't,,i4e;i'r'l,?.„4:17.;:',,"r`...^A.;,4'.'r'!',,,.;,t-.,4f ,,...; s".;'.i";;..4.;4;,.t.47., ,;4'-,'''•-„',,'v",..'A.''7''24 0-,--,4-',"A,`.44:1, 4”4: 14-15.(#4) • •Hilcorp Alaska • U Suspended Well Location Quarter Mile Radius Map SRU 331-27 SRU 21-22 iRU_11-22 — 000 2,000 FEET • • POSTED WELL DATA Well Label • WELL SYMBOLS SRU 32-22 Abandoned Well 5RU 412-22 — Dry Hole • Oil Well Plugged and Abandoned CJ Shut-in Well September 2,2015 SRU 23B-22 •SRU_23-22 C�- SRU_331-27 (#2) SRU .. -27 • PL SRU-24-22 • SRU_12-27 SRU 212-27 SF 3 -111)- SRU 32-27 • 3SF 2 SRU 23-27 314-27 SRU_314-27PB2 • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Suspended Well Inspection Report Date Inspected: 08/26/15 Inspector: Jeff Jones Operator: Hilcorp Well Name: SRF 331-27 Oper.Rep: Rick Musgrove PTD No.: 100-148 Oper.Phone: 907-283-2551 Location Verified? Yes Oper. Email: musgroveahilcorp.com If Verified,How? LAT/LONG Onshore/Offshore: Onshore Suspension Date: 09/16/14 Date AOGCC Notified: 08/04/15 Sundry No.: 314-416 Type of Inspection: Initial Wellbore Diagram Avail.? Yes Well Pressures(psi): Tubing 0 Photos Taken? Yes IA 10 OA 10 Condition of Wellhead: Good condition,valves and guages operable,no visible leaks.No flow line connected. Condition of Surrounding Surface Location: Good,clean gravel pad Follow Up Actions Needed: None Comments: Lat/Long taken from well sign Attachments: well head photo(1) REVIEWED BY: Well schematic Insp.Supry 3(2 17173115 Comm SCANNED SEP 0'7 2016 PLB 06/2014 2015-0826_Suspend_SRU_331-27jj.xlsx • • • igii.1.‘',1 -:k,l's:41-,,,,•-14 ,.-:-.(..., ,. . .....0. ,, , .,-, '.. ; - f.: YI ".e;.4, ,i, s 1 .. . y '., ' ii`, t `t r { II } Wt 1 t ALS€F'1'1W . r .t II': • k en en 4.4 6c 4 A ih4 _ ON W i o ' a 8y is ,1,$ ..,.' ',:t.,:tir; x O CI o: VD .1,'I',.}� f < J�l�Z 1[iF k O CD r � tai O O x t U V s. 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O V1A-+ A-to0 • 0 Swanson River Unit 11 Well: SRU 331-27 ACTUAL SCHEMATIC Completion Ran: 9/16/2014 Flan,,,Alaska,LLC PTD: 100-148 API: 50-133-10156-00 RKB:272'/GL:257'AWL Casing Detail KB-THF:15.0' Size Type Wt Grade ID Top Btm Hole Cmt Cmt Top 20" Conductor - - - Surf 22' - unknown Surf. 4170 20" ''' '1*1 i 18-%" 22' ;' 13-%" Surface 54.5 J-55 12.615" Surf 1,490' 1,500 sx Surf. 1,497' t; 112-%" 7" 29 P-110 6.184" Surf 1,027' n Kill Fluid .0!'k' 2,725' 41:,-;', 8,5 ppg *, 7" 29 N-80 6.184" 1,027' 2,172' 10-%" 13-3/8""., Lease Water " Prod Csg 11,659' 1,000 sx 9,140'CBL 1,490' 7" 26 N-80 6.276" 2,172' 8,192' „2 7" 29 N-80 6.184" 8,192' 10,695' SL,. e .A r7Csg ,, 1, Tested to 7" 29 P-110 6.184" 10,695' 11,620' Stuck@ ' _" 1,500 psi Tubing Detail CpIgOD unknown 9/15/14 depth 3.5" EUE 8RD 9.3 L-80 2.992" 4,311' 10,701' 1ij .1, ` r L 77. 4.500" Suspect •' M, 311111 1 I,411•41 Jewelry Detail Downhole ' w No. Depth ID OD Item Cable '' ` 1 1,023' 2.992" 3.500" 3-1/2"EUE 8RD Kill String(33 jts) FailureObstruction Unknown " @ 2 4,306' - - Cement Retainer,Squeeze 90 bbl 15.8 ppg cement below depth t z ': 7,210'SLM 3 5,853' 2.992" 5.313" Gaslift Mandrel,Camco MM,Live Valve 6`‘ l 2.50"LIB 4,14 er 4 7,974' 2.992" 5.313" Gaslift Mandrel,Camco MM,Live Valve CBLTOC I 5 10,600' 2.992" 5.313" Gaslift Mandrel,Camco MM,No Valve 9,140' , 1, 6 10,701' - 4.000" Top of ESP,Discharge Head t V- , d 7 10,788' 4.000" ESP Intake .I 5 � 8 10,788' 4.950" 5.500" ESP Shroud(31'of 5-1/2"15.5#Casing) w ; 2 9 10,820' - 5.520" Base of ESP,456 series Motor/400 series Pumps i, 1 = 4, 10 11,077' - - Lost 7 ea%"SS bands(5.8"GR tagged on bottom 11/16/13) Tag Pump 4114 �" "." 6 11 11,077' - - Cement Retainer,Capped w/10 sx cement 10,720'SLM te` a 2.35"GR i, 7 , Cable/Clamp/Band Detail 5/31/14 a , 1;,,,,,m2,,,, , 10,800'-10,820' - 8 ea 4560 Cannon Clamps(Across Motor Only) " ' 10,701'-10,800' - 18 ea 4010 Cannon Clamps(Across Pumps/Poseidon Gas Handler/Protector) 'n 10,671'-10,701' - 9 ea' "SS bands(all on 1s`joint above discharge 9 g head) 0'-10,671' - 3 ea' "SS bands per tubing joint(additional 1 ea for flatpack every other joint) *. k /14 2"(Total of 1184 SS bands) 0'-10,680' - 1 ea Reda#1 Round ESP Cable(Splices at approx.35', 159', 5,912',and 10,680') H-4 10,680'-10,800' - 1 ea MLE Flat Cable(Splice depth at approx..10,680') ill.'"". "^"`', 0'-10,702' - 1 ea Dual Flatpack Encapsulated Control Lines(2 ea Chem Inj) 10,702'-10,820' - 1 ea Tri Flatpack Encapsulated Control Lines(2 ea Chem Inj,1 ea Phoenix) a � H-5 *� 71 Perforation History e" wso Date Zone Top(MD) Btm(MD) Top(MD) Btm(MD) Amt spf Comments ( " H-6 12/11/58 WSO 10,795' 10,796' 10,795' 10,796' 1' 4 ,`a1l 12/14/58 H-4 10,804' 10,836' 10,804' 10,836' 32' 4 Squeezed :. 1458 / /- H 7 q Milled K 12 H-5 10,849' 10,878' 10,849' 10,878' 29' 4 Squeezed �: retainer u�. `° 12/11/58 WSO 10,880' 10,881' 10,880' 10,881' 1' 4 to • 4 H-10 11,077' ,4 10 Airy Hemlock 8/31/2012 H-6 10,906' 10,916' 10,906' 10,916' 10' 6 2.5"Owen 11 , ' 8/31/2012 H-7 10,926' 10,948' 10,926' 10,948' 22' 6 2.5"Owen �?; 12/09/58 Hemlock 11,038' 11,060' 11,038' 11,060' 22' 4 Open 7 j =_3 Hemlock 8/31/2012 H-10 11,050' 11,076' 11,050' 11,076' 26' 6 2.5"Owen 11,620 .., " r a . , TD=12,046' PBTD=11,077' 12/07/58 Hemlock 11,185' 11,195' 11,185' 11,195' 10' 4 Isolated Downhole Revised: 9/16/14 Revised By STP 9/22/14 ECpEIVED STATE OF ALASKA • ALI- ..A OIL AND GAS CONSERVATION COM,_..�SION FEB 1 8 2015 . WELL COMPLETION OR RECOMPLETION REPORT AND LOGr.r. la.Well Sta Oil I Gas ❑ SPLUG ❑ Other ❑ Abandoned ❑ • Suspended C `1 b.Well Class: 20AAC 25.105 20AAC 25.110 Development ❑✓ ' Exploratory ❑ GINJ ❑ WINJ ❑ WAG ❑ WDSPL❑ No.of Completions: _0 Service ❑ Stratigraphic Test ❑ 2.Operator Name: 5.Date CompiSusp.,or 12. Permit to Drill Number: Hilcorp Alaska.LLC Aband.: 9/16/2014 . 100-148/314-416 3.Address: 6. Date Spudded: 13.API Number: 3800 Centerpoint Drive.Suite 1400,Anchorage,AK 99503 11/10/1957 • 50-133-10156-00 4a. Location of Well(Governmental Section): 7. Date TD Reached: 14.Well Name and Number: Surface: 14'FSL, 1686'FEL,Sec.22,T8N, R9W, SM,AK 2/15/1958 Swanson River Unit(SRU)331-27• Top of Productive Horizon: 8. KB(ft above MSL): 272' 15. Field/Pool(s): GL(ft above MSL): 257' Total Depth: 9. Plug Back Depth(MD+TVD): Swanson River/Hemlock Oil • 14'FSL, 1686'FEL,Sec. 22,T8N, R9W, SM,AK • 11,077'MD/11,077'TVD • 4b. Location of Well(State Base Plane Coordinates, NAD 27): 10.Total Depth(MD+TVD): 16. Property Designation: Surface: x- 351343.6 y- 2471680.7 Zone- 4 • 12,046'MD/ 12,046'TVD, FEDA028406 ' TPI: x- y- Zone- 4 11. SSSV Depth(MD+TVD): 17. Land Use Permit: Total Depth: x- 351343.6 y- 2471680.7 Zone- 4 N/A N/A 18. Directional Survey: Yes ❑ No El 19.Water Depth, if Offshore: 20.Thickness of Permafrost MD/TVD: (Submit electronic and printed information per 20 AAC 25.050) N/A (ft MSL) N/A 21. Logs Obtained(List all logs here and submit electronic and printed information per 20AAC25.071): 22.Re-drill/Lateral Top Window MC/TVD: N/A N/A 23. CASING, LINER AND CEMENTING RECORD WT PER SETTING DEPTH MD SETTING DEPTH TVD AMOUNT CASING GRADE TOP BOTTOM TOP BOTTOM HOLE SIZE CEMENTING RECORD PULLED 20" 0 22' 0 22' Driven N/A 0 13-3/8" • 54.5 J-55 0 1,490' 0 1,490' 18-5/8" 1500 sx const 0 7" ▪ 26.29 P110 N80 0 11,620' 0 11.620' 10-5/8" 1000 sx const 0 24.Open to production or injection? Yes ❑ No E 25. TUBING RECORD If Yes, list each interval open(MD+TVD of Top and Bottom; Perforation SIZE DEPTH SET(MD) PACKER SET(MD/TVD) Size and Number): 3.5" 10,701' N/A 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. . tole III Was hydraulic fracturing used during completion? Yes H No DEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED N/A r„ I SCANNED APR 2 4 2015 27. PRODUCTION TEST Date First Production: Method of Operation(Flowing,gas lift,etc.): N/A Date of Test: Hours Tested: Production for Oil-Bbl: Gas-MCF: Water-Bbl: Choke Size: Gas-Oil Ratio: Test Period Flow Tubing Casing Press: Calculated Oil-Bbl: Gas-MCF: Water-Bbl: Oil Gravity-API(corr): Press. 24-Hour Rate -► 28. CORE DATA Conventional Core(s)Acquired? Yes ❑ No E . Sidewall Cores Acquired? Yes ❑ No 0 If Yes to either question,list formations and intervals cored(MD+TVD of top and bottom of each),and summarize lithology and presence of oil,gas or water (submit separate sheets with this form,if needed).Submit detailed descriptions,core chips,photographs and laboratory analytical results per 20 AAC 25.071. Form 10-407 Revised 10/2012 Zo 1 CONTINUED ON EVE SE `,b 4-ZZ• Iii Submit original onlyii- .c ��d/� ! RBDMS\H-- FEB 2 3 2015 t.1 29. GEOLOGIC MARKERS (List all formations and markers encountered): 30. FORMATION TESTS NAME MD TVD Well tested? ❑ Yes 2 No . If yes,list intervals and formations tested, briefly summarizing test results.Attach separate sheets to this form, if Permafrost-Top needed,and submit detailed test information per 20 AAC 25.071. Permafrost-Base Formation at total depth: 31. List of Attachments: Well Operations Summary,Schematic,Surface Casing Test 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Stan Porhola Email: sporholat�hilcom.Com Printed Name: Stan Porhola Title: Operations Engineer Signature: /ate Phone: 907-777-8412 Date: 2.-7/8//5" INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. Item 1b: Classification of Service wells: Gas Injection,Water Injection,Water-Alternating-Gas Injection,Salt Water Disposal,Water Supply for Injection,Observation,or Other.Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 4b: TPI(Top of Producing Interval). Item 8: The Kelly Bushing and Ground Level elevations in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13: The API number reported to AOGCC must be 14 digits(ex:50-029-20123-00-00). Item 20: Report true vertical thickness of permafrost in Box 20. Provide MD and ND for the top and base of permafrost in Box 28. Item 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 24: If this well is completed for separate production from more than one interval(multiple completion),so state in item 1,and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced,showing the data pertinent to such interval). Item 27: Method of Operation: Flowing,Gas Lift,Rod Pump,Hydraulic Pump,Submersible,Water Injection,Gas Injection,Shut-in,or Other (explain). Item 28: Provide a listing of intervals cored and the corresponding formations,and a brief description in this box. Submit detailed description and analytical laboratory information required by 20 AAC 25.071. Item 30: Provide a listing of intervals tested and the corresponding formation,and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10-407 Revised 10/2012 Hilcorp Alaska, LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date SRU 331-27 50-133-10156-00 100-148 8/29/14 9/16/14 Daily Operations: 08/29/2014- Friday Hold JSA shift change. Stage and move equipment. MIRU Moncla 401. Finish spotting and rigging pump tanks flow lines. N/U and shell test BOPE. 08/30/2014-Saturday Shift Change, hold JSA. Finish rig up and prep for BOPE test. Test BOPE and Koomey. Prep to pull pipe, install lift sub, start to pull on pipe, pull to 165k, no movement, order jars. P/U 4 3/4" oil jar, 2 accelerator jars, 1 xover and screw into hanger, start jarring, set off jars at 120k and pull to 165k,get very little movement. 08/31/2014-Sunday Shift change, hold JSA. Work pipe up to 185k, about 20 inches of movement, work pipe and pump 200 bbls of FSW down annulus while working pipe, no change in pipe movement. MIRU S/L, RIH with 2.50" bailer, set down at 7,406' SLM. POOH, shift change, hold JSA. Pump 200 bbls dowm tubing, attempt to circulate, no luck. RIH with 1.75" bailer and tag at 10,693 ft SLM. Work pipe up to 185k, no new movement, still 20 inches. 09/01/2014- Monday Safety Meeting,JSA. Work pipe from 165 - 185 k, no futher movement. Wait on orders. Rig crew helped Expeditor clean locations. Prep to cut pipe. MIRU Pollard E-Line to freepoint pipe, find bottom free point at 3,794 ft ELM. POOH, RIH with 2.70" OD jet cutter and cut pipe at 3,765 ft ELM, lose 100K weight string, weight now 47K. RDMO E-Line. POOH and L/D hanger. P/U sheaves for REDA cable and flatpack. POOH and standback 118 jts 3,762 ft TBM of 3-1/2" EUE 8 rd tubing 9.3 PPF and spool up REDA Cable and flat packs. 09/02/2014-Tuesday Shift change, hold JSA. RIH with LIB 5.75" OD tag 3,786 ft, no marks on face, some on edges. POOH. RIH with 5.50" LIB, marks on edges, no marks on face, tag same spot at 3,786'. POOH, RIH with 2.80" LIB, find marks on face consistent with top of fish, tag 3,787 ft SLM. POOH, RIH 4.0" overshot,find few marks on face. POOH. RIH with 5.0" LIB, find marks on edge from maybe REDA cable. Wait on tools from KNIGHT, sent out wrong grapple and crossover. M/U BHA: 1-dress off guide OD 4-11/16" - ID 3-3/4" L .58"; 1 lower ext OD 4-11/16" - ID 3-11/16" L 3.0"; bowl OD 4-5/8" L 1.27"; upper ext OD 4-11/16" - ID 3-11/16" L 3.0"; top sub 4-5/8" - ID 1-3/4" L 1.15"; xover OD 4-3/4" - ID 2.0" L 1.69"; bumper jar OD 4-3/4" - ID 2-1/4" L 10.75"; oil jar 4-3/4" - ID 2-1/4", L 9.70"; 6 DC's OD 4-11/16" -ID 2-5/16" L 184.18"; intensifier jar 4-3/4" - ID 2-1/4" L 15.05"; xover 4-11/16" - ID 2-3/4" L 1.10" =TOTAL length of BHA 231.67". RIH with tbg 112 jts 3-1/2" 8 rd, tag top of fish 3,785 ft TBM. P/U power swivel and dress off top of fish swallow 6 ft. P/U to 60K, fish engaged. R/D power swivel stand back in derrick . 09/03/2014-Wednesday Hilcorp Alaska, LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date SRU 331-27 50-133-10156-00 100-148 8/29/14 9/16/14 Daily Operations: Shift change, Hold JSA. Work pipe set off jars, grapple, break loose fish, inspect rig. Find kink in drill line, have to cut and slip drill line. POOH 112 jts 3-1/2" tbg, 6 4-3/4" DC's, 1 acc jar, 1 oil jar, 1 bumper jar, and overshot,find cut lip guide split and ball of REDA cable inside overshot. RIH with 5-3/4" overshot, rest of BHA the same, 112 jts 3-1/2" tbg, engage fish @ 3,798 ft TBM, 6 ft deeper than before work, overshot down swallow 6 ft tbg. Work pipe, set jars off 100k, pull to 165k, make no hole, load tubing to keep jars cool, 56 bbls FSW and load again in prep for eline 32 bbls. Shift change, hold JSA. MIRU Pollard E- Line. RIH with 1-11/16" tubing punch, punch holes at 4,210'-4,212 ft ELM, 10 holes. POOH, RIH with 2" radial torch cutter and cut pipe at 4,211 ft ELM, log back down, show 1 ft separation in pipe. RDMO E-Line. Start pulling pipe, pipe moving 4,000 lb overpull. Pull 8 jts pipe, hang up, work free, pipe dragging coming out of hole 2-6K over. Find wad of cable below top of fish, cut free. L/D top of fish, continue pulling pipe, no REDA cable on pipe, flat pack still intact. 09/04/2014-Thursday Shift change, Hold JSA, discuss PPE. Finish POOH with fish and tally prep for slickline. MIRU slickline. RIH with 5.75" LIB to tag at 3,589' SLM. POOH,find wire marks on face. RDMO slickline. RIH with screw grab to tag at 3,610 ft TBM. Torque pipe with tongs, torque up, make 4 ft hole. P/U weight 1k more. POOH, S/B tbg, get screw grab to surface, no cable, had maybe 20 bands on grab. RIH with screw grab to 3,610 ft and tag up. R/U swivel and work to 3,620 ft. POOH, S/B tbg, get screw grab to surface, have ball of cable, est 30-50 ft clean grab. RIH with screw grab to 3,615 ft. Transmission breakdown on rig, make repairs. P/U P/S tag up work downhole to 3,620 ft, torque up, quit making hole, pull 25 k over, set off jars to get free. R/D P/S pulling 5k over coming out of hole. 09/05/2014- Friday Shift change, Hold JSA, discuss locking gate and speed on Swanson Rd. POOH with screw grab, have 15 ft cable bands and fill in grab. RIH with screw grab, tag 3,615 ft. R/U P/S pump 180 bbls FSW down, B/S attempt to circulate, no returns, make hole to 3,620'. R/D P/S. POOH with screw grab, 15-20 ft of cable in grab. RIH with screw grab, tag 3,620 ft. P/U power swivel, work down to 3,625'. R/D P/S. POOH, S/B to screw grab, 20 ft cable in grab. RIH with screw grab to 3,622 ft tag. R/U P/S work pipe pulling 6K over. Start POOH with TBG, pull 6 stands tubing pulling wet. R/U mud bucket, continue to pull pipe. 09/06/2014-Saturday Shift Change, Hold JSA. Finish pulling out of hole with pipe, remove approx 20 ft cable with grab. BOPE test. 250 low- 3,000 high. Witness wavied by Jim Regg, AOGCC. Make screw grab run to 3,621 ft. POOH, recover no cable. Make screw grab, run to 3,621', make hole to 3,625 ft. POOH, recover 20 ft cable. Recovered app. 125 ft of cable so far. Make a screw grab run to tag at 3,625 ft, chase downhole to 3,801 ft, tag again. POOH, recover 5 ft cable. Make a screw grab, run to tag at 3,801 ft. P/U power swivel, work pipe, shift change. 09/07/2014-Sunday Shift change, Hold JSA. Work pipe with swivel down to 3,875 ft. POOH, recover 5 ft cable. RIH with screw grab, tag at 3,875 ft, work down with swivel to 3,879 ft. POOH, S/B, recover 10 ft cable. RIH with screw grab to tag at 3,879 ft, work down with swivel to 4,009 ft. POOH, S/B, recover 20 ft cable. RIH with screw grab to tag at 4,016 ft, work down with swivel to 4,019 ft. POOH, S/B, recover 5 ft cable. RIH with screw grab to tag at 4,014 ft, work down with swivel to 4,020 ft, shift change. 09/08/2014- Monday Hilcorp Alaska, LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date SRU 331-27 50-133-10156-00 100-148 8/29/14 9/16/14 Daily Operations: Shift change, Hold JSA. POOH, S/B tubing, recover 5 ft cable. RIH with screw grab, tag at 3,875 ft, work pipe down to 4,009' ft, tag hard swivel torquing up bad. POOH, S/B, recover 10 ft cable. RIH with screw grab tag at 4,010 ft, work pipe down to 4,048 ft. POOH, recovered small piece of power cable. MU 5-3/4" Hook Basket, 2 jts of 5-1/2" Washpipe, 5-3/4" Top Bushing, 4-3/4" Oil Jars, 6 4-11/16" Drill Collars and Tallied BHA. Total length 272.75'. TIH w/ BHA 3-1/2"rd. Tag fish at 4,048'. SD to make Repairs on the Rig transmission. No rig charge while repairs made. RU Power swivel and started washing over fish at report time. 09/09/2014-Tuesday Held JSA with Rig Crew and Rig Support. Worked BHA down from 4,048' to 4,126' while pumping 1 bpm. Well started circulating then the tbg plugged up. Pressured up to 1,500psi with no luck. With tbg plugged up decided to POOH. PU mud bucket and RU vac truck. POOH with tbg wet. L/D first jt of washpipe with 15' of fill (mainly cable insulation), L/D the second washpipe with 5' of cable inside. L/D the shoe with 50+ pounds of cable inside. Cleaned on shoe to make other run. TIH w/same BHA and tagged at 4,099'. Circulated 2 well volumes, returns were small pieces of power cable. Worked BHA down to 4,159'. Tbg plugged off and decided to trip. PU mud bucket and RU vac truck. POOH with tbg wet. Cleaned out washpipe and shoe. Recovered 15'to 20' of power cable. TIH w/same BHA and tagged at 4,159'. RU Power Swivel and started circulating. 09/10/2014-Wednesday Crew change/Held JSA. Broke circulation and started washing. Milled down to 4,190' and tbg plugged off. TOOH and L/D Washpipe and Shoe. Recovered 10'to 12' of power cable. MU and 12' spear and tallied BHA. TIH hole 15 stands and SD for a safety stand down. Safety Stand Down. TIH w/the stands in the derrick. Scoped the derrick in at half mast and installed new SRL cable. 09/11/2014-Thursday Held JSA. Worked spear to engage fish, with 2k over pull decided to TOOH. TOOH w/spear, No fish recovered. TIH w/spear and engaged fish at 4,191', Worked spear and latched fish. TOOH with 5k over pull, Lost fish at tbg hanger, mondified spear and worked fish thru BOP stack, recovered 30'. TIH w/spear and engaged fish at 4,206', worked tool and latched fish. TOOH w/spear and recovered 40'. TIH w/spear and engaged fish at 4,226',worked tool and latched fish. TOOH at report time. 09/12/2014- Friday Held JSA. TOOH w/spear, Recovered 50' of cable. TIH w/spear, SD Due to Transmission leak on Rig. SD replace Rig Transmission. 09/13/2014-Saturday SD to Replace Rig Transmission. Finished repairs on rig. Engaged fish with spear at 4,240' RKB. Worked tool and latched fish. Started TOOH. 09/14/2014-Sunday Hilcorp Alaska, LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date SRU 331-27 50-133-10156-00 100-148 8/29/14 9/16/14 Daily Operations: Crew Change, Held JSA. TOOH w/Spear, recovered 40' of cable. L/D spear. Spear had 7 hooks broke off, 3 in the well and 4 in the cable. Prep to test BOP's for weekly test. Test BOP's per AOGCC (witness waived by Jim Regg, AOGCC),valves 250- 3,000psi, Rams 250-3,000psi, Annular 250-3,000psi. Performed Gas Detection and Koomey Draw Down. No failures recorded. TIH w/8' spear to 4,308', Rotated spear and POOH. TOOH w/spear, Recovered 30' of cable. Looks like cut end off cable. L/D spear. MU 5-3/4" Burnshoe, 1 jt of 5-1/2" washpipe, bushing oil jars and 6 DC and tallied. TIH and dressed 7' over cut jt at 4,310', Torqued up several times while dressing around cut. TOOH and LD burnshoe and washpipe. MU slick assembly and tallied. TIH and tagged 4,310'. Set down 20k over on TOF, PU to 10k down on fish and spaced out to rig floor, Set slips. MIRU EL and report time. 09/15/2014- Monday Held JSA, Continued TIH w/2-3/4" Jet cutter,Tagged at 4,307'. POOH. MU CCL and TIH, tagged hard at 4,311', could not work tool thru. POOH. TOOH and L/D slick assembly. MU Fishing BHA and tallied. TIH w/cutlip guide and OS and tagged at 4,311', tried to work over fish with no luck. TOOH and L/D fishing BHA. MU 5.75" cement retainer and TIH at set retainer at 4,306'. Confirmed set w/10k down. Unstung out of retainer and pump 148 bbls, pressured up to 1,500psi and tested for 30 mins. MIRU SLB Cement equipment. Performed injections test at 4 bpm. Mixed 90 bbls of 15.8#cement. Pumped 90 bbls of cement down the tbg at 4bpm, Displaced workstring with 38 bbls and SD. RDMO SLB Cementing equipment. 2 09/16/2014-Tuesday Held JSA,TOOH with mechanical setting tool and LD. TIH w/33 jts of 3-1/2" for kill string. MU Tbg Hanger and landed, Secured lockdown pins. ND 7" BOP stack, NU dry hole tree and tested to 5,000psi. RDMO Moncla 401 and associated equipment. Swanson River Unit - II Well: SRU 331-27 ACTUAL SCHEMATIC Completion Ran: 9/16/2014 Hilcora Alaska,LLC PTD: 100-148 API: 50-133-10156-00 RKB:272'/GL:257'AMSL Casing Detail KB-THF:15.0' Size Type Wt Grade ID Top Btm Hole Cmt Cmt Top 0" .i-..* - 1 20" Conductor - - - Surf 22' - unknown Surf. 5 l'"' H 22 ` 0 , 13-%" Surface 54.5 1-55 12.615" Surf 1,490' 1 497 1,500 sx Surf. Pet 1IP12�' ! 7" 29 P-110 6.184" Surf 1,027' Kill Fluid 2,725 `�! 8.5 ppg 7" 29 N-80 6.184" 1,027' 2,172' 10-%" 13-3/8" Lease Water Prod Csg 11,659' 1,000 sx 9,140'CBL 1,490' 7" 26 N-80 6.276" 2,172' 8,192' 4 30` iv, w2 7„Csg 7" 29 N-80 6.184" 8,192' 10,695' 01 ..• Tested to 7" 29 P-110 6.184" 10,695' 11,620' Stuck @ �` 0 1,500 psi Tubing Detail Cplg OD unknown 9/15/14 depth a, F 3.5" EUE 8RD 9.3 L-80 2.992" 4,311' 10,701' ' _ 4.500" M Jewelry Detail Suspect Downhole Sr'5 No. Depth ID OD Item Cable • y- It", 1 1,023' 2.992" 3.500" 3-1/2"EUE 8RD Kill String(33 jts) Failure @ r Obstruction Unknown @ 2 4,306' Cement Retainer,Squeeze 90 bbl 15.8 ppg cement below 41 depth %,r �` 7,210'SLM 3 5,853' 2.992" 5.313" Gaslift Mandrel,Camco MM,Live Valve 1 , 2.50 LIB 4 7,974' 2.992" 5.313" Gaslift Mandrel,Camco MM,Live Valve CBL TOC 5 10,600' 2.992" 5.313" Gaslift Mandrel,Camco MM,No Valve 9,140' •; 6 10,701' - 4.000" Top of ESP,Discharge Head 7 10,788' 4.000" ESP Intake 11111, 1 5 8 10,788' 4.950" 5.500" ESP Shroud(31'of 5-1/2"15.5#Casing) !` J 9 10,820' - 5.520" Base of ESP,456 series Motor/400 series Pumps Tag Pump '°iF' 10 11,077' Lost 7 ea%"55 bands(5.8"GR tagged on bottom 11/16/13) @ 6 4:A. 11 11,077' - - Cement Retainer,Capped w/10 sx cement 10,720'SLM ? k�' 14 2.35"GR 4t 5/31/14 Cable/Clamp/Band Detail 10,800'I -10,820' - 8 ea 4560 Cannon Clamps(Across Motor Only) 8 10,701'-10,800' - 18 ea 4010 Cannon Clamps(Across Pumps/Poseidon Gas Handler/Protector) . 9 P„44% 10,671'-10,701' - 9 ea 3/4"SS bands(all on 1st joint above discharge head) t 0'-10,671' - 3 ea%"SS bands per tubing joint(additional 1 ea for flatpack every other joint) ;49i WSO (Total of 1184 SS bands) i16 0'-10,680' - 1 ea Reda#1 Round ESP Cable(Splices at approx.35',159', 5,912',and 10,680') ; .. H-4 10,680'-10,800' - 1 ea MLE Flat Cable(Splice depth at approx..10,680') 0'-10,702' - 1 ea Dual Flatpack Encapsulated Control Lines(2 ea Chem Inj) "I k.,i 10,702'-10,820' - 1 ea Tri Flatpack Encapsulated Control Lines(2 ea Chem Inj,1 ea Phoenix) '4,-*. E } H-5 Perforation History 1 4... Wso Date Zone Top(MD) Btm(MD) Top(MD) Btm(MD) Amt spf Comments , 44, 1 H-6 12/11/58 WSO 10,795' 10,796' 10,795' 10,796' 1' 4 i,` 12/14/58 H-4 10,804' 10,836' 10,804' 10,836' 32' 4 Squeezed � H-7 Milled K '�" 12/14/58 H-5 10,849' 10,878' 10,849' 10,878' 29' 4 Squeezed retainer l,,,, 12/11/58 WSO 10,880' 10,881' 10,880' 10,881' 1' 4 to H-10 11,077' .�+1 10 c Hemlock 8/31/2012 H-6 10,906' 10,916' 10,906' 10,916' 10' 6 2.5"Owen 11 ?» 3„ ,_ _IL,..*, -' 8/31/2012 H-7 10,926' 10,948' 10,926' 10,948' 22' 6 2.5"Owen ►, ! 12/09/58 Hemlock 11,038' 11,060' 11,038' 11,060' 22' 4 Open 7.. # Hemlock 8/31/2012 H-10 11,050' 11,076' 11,050' 11,076' 26' 6 2.5"Owen 11,620't,i ro » TD=12,046' PBTD=11,077' 12/07/58 Hemlock 11,185' 11,195' 11,185' 11,195' 10' 4 Isolated Downhole Revised:9/16/14 Revised By STP 9/22/14 r �15 I ,X77: di-.7 --- -AMNON r----- ',IPAI oigNIN„. --- __1,:, ' rall 441.4.NN I � VI I �CH ♦ "� tk:\ , NQ. sf ________ 0H AR• ���. ART pUT ON Orr. , :_ l o • t1 � �+ --� TAKEN OFF't 1 la \"„�l�t ��`���`��� REMARKSS/1� ,33�-e27 ` ��i , �� 4rCcs. 7- r7-}4 ::(40/04„-,/ ii - � ��� � � � i 1111111 �� `� ,.., � y ,,�,,et,(,00,, i �� r�� �.�, ��10747pritirOle II 'j ��'���14,\VALaektit �'�� � � .�s> rig- _ _ � • , s,�i,♦ �/ / \\I\ It..VN `�� , �� tt044.11111i4tie 4# r �� 'I'//// / 1 V4 (V. At...s. '' • iS ` alail 1 160WWS4 0 1; � 4:‘"*\,4***44• \ �41 ,111116 $44#4. # Abb'‘.‘141,471110141160‘,..1 Wd 9 9 Schwartz, Guy L (DOA) From: Schwartz, Guy L(DOA) Sent: Friday, September 12, 2014 2:51 PM To: 'Stan Porhola' Subject: RE: Possible change to SRU 331-27 plugback(PTD 100-148) (Sundry 314-416) Stan, You have approval to modify the existing sundry 314-416 as proposed below. Variance to plugging well as required by per 20 AAC 25.112(c) (1)(D) is granted... retainer set above "fish" then down squeezing with 85bbls cement is an acceptable alternative and will adequately isolate the reservoir and protect freshwater resources. Guy Schwartz Senior Petroleum Engineer AOGCC SCANNED ; P? '2 4 2015 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). From: Stan Porhola [mailto:sporhola@hilcorp.com] Sent: Friday, September 12, 2014 2:42 PM To: Schwartz, Guy L(DOA) Subject: RE: Possible change to SRU 331-27 plugback(PTD 100-148) (Sundry 314-416) Guy, Per our phone conversation, below is the proposed abandonment with variance request for alternative plug placement for SRU 331-27 (PTD 100-148). 1.) Continue attempts to remove cable to clear well down to radial torch cut 3-1/2" tubing at 4,311'. 2.) If unable to recover all cable down to fish or unable to jar fish free at 4,311': 3.) Confirm ability to establish circulation down the 7" casing below the tubing cut. 4.) Run in hole with 7" cement retainer and set at+/-4,310'. 5.) Test casing and retainer to 1,500 psi for 30 min. 6.) Tag retainer w/ 10K. Stab into retainer and mix and pump 85 bbl cement and squeeze below the cement retainer. a. Request variance to 20AAC25.112(c)(1)(D) for alternative plug placement to place plug+/-6,600' above top perfs. 7.) POOH. L/D 3-1/2" tubing. Set BPV. ND BOPE. NU Dry hole tree. Future plans(to be included in a new 10-403 sundry submittal): 1.) Remobilize Moncla #401. 2.) Cut and recover 7" casing down to+/-4,300'. 3.) Demobilize Moncla#401. 4.) Mobilize Saxon#169. 5.) Cleanout to casing cut point (+/-4,300'). 6.) Drill ahead to next casing point (+/- 10,000'). 7.) Run new production casing(i' or 7-5/8" or 9-5/8"). 8.) Drill liner section to TD. 9.) Run production liner(4-1/2" or 5-1/2"). 10.)Demobilize Saxon #169. 11.) Remobilize Moncla #401. 12.)Run new completion. 13.)Demobilize Moncla #401. Stan From: Stan Porhola Sent: Friday, September 12, 2014 9:47 AM To: guy.schwartz@alaska.gov Cc: victoria.ferguson@alaska.gov Subject: Possible change to SRU 331-27 plugback(PTD 100-148) (Sundry 314-416) Guy, We are having issues pulling the failed ESP in SRU 331-27.The tubing is stuck at an unknown depth below our most recent cut at 4,310'. In the event we can make no further progress on fishing out the tubing and ESP cable and flatpack,we are proposing to plugback with a cement retainer at our current depth. Future plans would be to cut and recover the 7" casing and sidetrack the well from a shallower depth. Attached are the current and proposed schematics. I am out at Swanson River. Please give me a call on my cell phone at your nearest convenience to discuss. Regards, Stan Porhola I Operations Engineer North Kenai Asset Team Hilcorp Alaska,LLC sporhola@hilcorp.com Office: (907) 777-8412 Mobile: (907) 331-8228 2 Schwartz, Guy L (DOA) From: Schwartz, Guy L (DOA) Sent: Friday, September 12, 2014 2:51 PM To: 'Stan Porhola' Subject: RE: Possible change to SRU 331-27 plugback (PTD 100-148) (Sundry 314-416) Stan, You have approval to modify the existing sundry 314-416 as proposed below. Variance to plugging well as required by per 20 AAC 25.112(c) (1)(D) is granted... retainer set above "fish" then down squeezing with 85bbls cement is an acceptable alternative and will adequately isolate the reservoir and protect freshwater resources. Guy Schwartz Senior Petroleum Engineer AOGCC 907-301-4533 cell 907-793-1226 office CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Guy Schwartz at (907-793-1226 ) or (Guv.schwartz@alaska.gov). From: Stan Porhola [mailto:sporhola@hilcorp.com] Sent: Friday, September 12, 2014 2:42 PM To: Schwartz, Guy L (DOA) Subject: RE: Possible change to SRU 331-27 plugback (PTD 100-148) (Sundry 314-416) Guy, Per our phone conversation, below is the proposed abandonment with variance request for alternative plug placement for SRU 331-27 (PTD 100-148). 1.) Continue attempts to remove cable to clear well down to radial torch cut 3-1/2" tubing at 4,311'. 2.) If unable to recover all cable down to fish or unable to jar fish free at 4,311': 3.) Confirm ability to establish circulation down the 7" casing below the tubing cut. 4.) Run in hole with 7" cement retainer and set at +/- 4,310'. 5.) Test casing and retainer to 1,500 psi for 30 min. 6.) Tag retainer w/ 10K. Stab into retainer and mix and pump 85 bbl cement and squeeze below the cement retainer. Request variance to 20AAC25.112(c)(1)(D) for alternative plug placement to place plug +/- 6,600' above top perfs. 7.) POOH. L/D 3-1/2" tubing. Set BPV. ND BOPE. NU Dry hole tree. Future plans (to be included in a new 10-403 sundry submittal): 1.) Remobilize Moncla #401. 2.) Cut and recover 7" casing down to +/- 4,300'. SCANNEI) OCT 0 1. 2014. 3.) Demobilize Moncla #401. 4.) Mobilize Saxon #169. 5.) Cleanout to casing cut point (+/- 4,300'). 6.) Drill ahead to next casing point (+/- 10,000'). 7.) Run new production casing (7" or 7-5/8" or 9-5/8") 8.) Drill liner section to TD. 9.) Run production liner (4-1/2" or 5-1/2"). 10.) Demobilize Saxon #169. 11.) Remobilize Moncla #401. 12.) Run new completion. 13.) Demobilize Moncla #401. Stan From: Stan Porhola Sent: Friday, September 12, 2014 9:47 AM To: guy.schwartz@alaska.gov Cc: victoria.ferguson0)alaska.gov Subject: Possible change to SRU 331-27 plugback (PTD 100-148) (Sundry 314-416) Guy, We are having issues pulling the failed ESP in SRU 331-27. The tubing is stuck at an unknown depth below our most recent cut at 4,310'. In the event we can make no further progress on fishing out the tubing and ESP cable and flatpack, we are proposing to plugback with a cement retainer at our current depth. Future plans would be to cut and recover the 7" casing and sidetrack the well from a shallower depth. Attached are the current and proposed schematics. I am out at Swanson River. Please give me a call on my cell phone at your nearest convenience to discuss. Regards, Stam Porhola j Operations Enginee" North. Kenai Asset'ream Hilcorp Alaska, LLC sporhola@hilcorp.com ()flice. (907) 777-8412 Mobile: (907) 331-8228 THE NATE tv i GOVERNOR SEAN PARNELL, Stan Porhola Operations Engineer Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 100 Anchorage, AK 99503 333 west Sevenih Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Pc,: 9^7 %76.7542 I" - l L+? Re: Swanson River Field, Hemlock Oil Pool, Swanson River Unit 331-27 Sundry Number: 314-416 Dear Mr. Porhola: 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, Cathy P. oerster Chair ty DATED this 2Jy of July, 2014. Encl. Hileorp Alaska, LL Well Prognosis Well: SRU 331-27 Date:7/11/2014 Well Name: SRU 331-27 API Number: 50-133-10156-00 Current Status: Shut -In ESP Oil Well Leg: N/A Estimated Start Date: July 21St, 2014 Rig: Moncla #401 Reg. Approval Req'd? 403 Date Reg. Approval Rec'vd: Regulatory Contact: Donna Ambruz 777-8305 Permit to Drill Number: 100-148 First Call Engineer: Stan Porhola (907) 777-8412 (0) (907) 331-8228 (M) Second Call Engineer: Paul Chan (907) 777-8333 (0) (907) 444-2881 (M) AFE Number: Current Bottom Hole Pressure: 3,117 psi @ 10,841' TVD (Static survey April 2012 mid perf of 10,841' MD) Maximum Expected BHP: - 3,117 psi @ 10,841' TVD (Static survey April 2012 mid perf of 10,841' MD) Max. Allowable Surface Pressure: 0 psi (2,350 psi gaslift) (Based on actual reservoir conditions and min water cut of 50% (0.385psi/ft) will balance reservoir pressure at 2,745 ft. TVD. Brief Well Summary This well was drilled and completed as an oil well in Hemlock benches H-4, H-5, & H-10 in 1958. A workover performed in 1963 isolated the H-10 and reperforate the H-4 & H-5 zones. A workover in 1971 converted the well to gas injection. Gas injection was halted in 1981 and the well remained shut in until 2012. A workover performed in 2012 was performed to pull tubing and packers, cement squeeze the H-4 and H-5, pressure test casing, drill out cement, pressure test squeeze, cleanout fill, BPs, perforate H-6, H-7, and H-10 and ran a GL completion. The gaslift completion was pulled and converted to ESP completion in mid-July 2013. Upon initial startup of the ESP, a downhole failure occurred. The ESP was pulled and found to have a downhole pump failure (yet to be determined). The gaslift completion was re -ran to put the well back on production until a new ESP pump can be delivered. A capillary string was installed in early August 2013 to help with existing emulsion issues. The capillary string and gaslift completion were pulled and an ESP installed in September 2013. The ESP failed in October 2013 and was pulled and replaced in November 2013. A downhole failure occurred in April 2014, and the well has produced intermittently using the existing gaslift mandrels. The purpose of this work/sundry is to plugback the well to prepare it for a sidetrack using Saxon #169. The Saxon #169 will use the 7" bridge plug at +/- 7,000' to set the whipstock. ts�Gvr. �vtk wl►.K fife o(dw„J�o(� Notes RegardingWellbore Condition wGf (on- a,, fir' 110Fr•� W �f�'t Q /Ddttt G,i�S"# f Weil q.o< r4c w4 ho, Cvf oat geabl.f /'1tPu'i • ESP is currently down (likely failed due to downhole cable failure). q f Ol/ pre) 4 c —,'vh WO Rig Procedure: pr.'or- To Tot "T r: 1 2, f1% f1%%vrf TA( w%r'4 4 90f IV 1. MIRU Moncla #401 WO Rig. rh .; A t En r /�C�r. ii tio��/ q � ow � ,,�rV 2. Set BPV. ND Tree. veto,-ery Fief Ti's `"e(cf. � 3. NU 7-1/16" BOPE. Set BPV. Test to 250 psi Low/ 3,000 psi High, annular to 250 psi Low/ 1,500 psi High (hold each valve and test for 10 -min). Record accumulator pre -charge pressures and chart tests. a. Notify AOGCC 24 hrs in advance of BOP test. Hilcorp Alaska, LLQ Well Prognosis Well: SRU 331-27 Date: 7/11/2014 b. Notify BLM 48 hrs in advance of BOP test. 4. Bleed any pressure off tubing. Pull BPV. 5. Kill well w/ 8.4 ppg lease water. 6. Back out tbg hanger hold down pins. 7. MU 3-1/2" landing joint and pull tubing hanger free. 8. SOOH and rack back the 3-1/2" tubing. Lay down the failed ESP Pump.- a. Schlumberger to send ESP components in for tear down analysis (including cable). b. Spool up the dual flat pack and tri -pack and send to CIFO for storage (may be junk). c. Send cannon clamps to CIFO for storage (may be junk). d. Junk the control line bands (total of 1,184 in the well). e. Make sure to have handling equipment for ESP Shroud (31' of 5-1/2" 15.5# casing). f. Send the 3-1/2" tubing hanger to CIFO for cleaning and redress. g. Tubing is 3-1/2" 8RD (100% Tensile = 207k). h. Send pulled 3-1/2" 8RD tubing to Tuboscope for inspection and cleaning (end of job). i. Add thread protectors (box and pin) on all joints pulled (+/- 350 jts). j. Send 3-1/2" GLM to Pollard for cleaning and redress. 9. PU 7" 29.0# casing scraper and 6" bit. a. Drift diameter of casing is 6.184". 10. RIH w/ casing scraper w/ 3-1/2" 8RD tubing to 11,077' to current PBTD. 11. POOH. Lay down casing scraper, bit, and rack back the 3-1/2" tubing. 12. PU 7" Cement Retainer w/ mechanical setting tool. 13. RIH w/ 7" Cement Retainer and set at 10,775'. e _`, i,. 7 6� 1 a. Correlate using pipe measurements (+/- 25'). t 0 14. Tag w/ 10k DWT to confirm set. 15. Fill well w/ 8.4 ppg lease water. 16. Test casing to 2,500 psi for 30 min and chart. 17. Stab into retainer and establish circulation below the retainer. 18. Mix and pump 20 bbl of 15.8 ppg cement below the retainer. a. Leave 1 bbl on top of retainer. 19. Unsting out of retainer. 20. Circulate well clean w/ 8.4 ppg lease water. 21. POOH. Lay down the 3-1/2" tubing and lay down the stab -in adapter. 22. RU E -line. a. MU flange to 7-1/16" 5M BOPE. 23. PU 7" Bridge Plug w/ E -line setting tool. 24. RIH w/ 7" Bridge Plug and set at 7,_00„0' (3'-5' above a collar). a. Correlate using CCL. 25. POOH. RD E -line. 26. Set BPV. ND 7-1/16" BOPE. NU dry hole tree. Pull BPV. 27. RD Moncla #401 WO Rig. 28. Turn well over to production. 29. Replace IA x OA pressure gauge if removed (7" x 13-3/8"). Drilling Rig Procedure: 30. MIRU Saxon #169 Drilling Rig. 31. Mix mud for 6" hole section. Hileorp Alaska, LL Well Prognosis Well: SRU 331-27 Date: 7/11/2014 32. Set test plug in wellhead. 33. NU 11" BOPE. Set BPV. Test to 250 psi Low/ 3,000 psi High, annular to 250 psi Low/ 2,500 psi High (hold each valve and test for 5 -min). Record accumulator pre -charge pressures and chart tests. a. Notify AOGCC 24 hrs in advance of BOP test. b. Notify BLM 48 hrs in advance of BOP test. 34. PU window milling assembly on 4" DP. 35. RIH to CIBP at 7,000'. 36. Circulate well clean w/ 8.4 ppg lease water. 37. Test casing to 2,500 psi for 30 min and chart. 38. SOOH and rack back milling assembly. 39. PU mills and UBHO sub on a joint of HWDP. 40. PU whipstock and attach mills and milling assembly. 41. Orient whipstock above CIBP. 42. Tag up on CIBP. Set whipstock anchor. Shear off window mill from the whipstock. 43. PU 5-10' above the whipstock. 44. Circulate well over to 9.5 ppg 6% KCI/PHPA drilling mud. 45. ***Remaining procedure to be included on the Permit to Drill for the sidetrack*** Attarhmontc• 1. As -built Schematic 2. Proposed Schematic 3. BOP Schematic 11ilcorp Alaska, LLC 20" 22' i 13-3/8" 1,490' Suspect Downhole Cable Failure @ Unknown depth CBLTOC 9,140' Tag Pump 10,720' SUM 2.35" GR 5/31/14 RKB: 272'/ GL: 257' AMSL KB - THF: 15.0' Obstruction 7,210' SLM 2.50" LIB WSO H-4 H-5 ws0 H-6 ACTUAL SCHEMATIC CaSinR Detail Swanson River Unit Well: SRU 331-27 Completion Ran: 11/19/2013 PTD: 100-148 API: 50-133-10156-00 Size Type Wt Grade ID Top Btm Hole Cmt Cmt Top 20" Conductor - 5.313" - Surf 22' - unknown Surf. 13-%" Surface 54.5 J-55 12.615" Surf 1,490' 18-%" 1,500 sx Surf. 1,497' 7" Prod Csg 29 P-110 6.184" Surf 1,027' 12-%" 2,725' 11000 sx 9,140' CBL 7" 29 N-80 6.184" 1,027' 2,172' 10-%" 111659' 7" 26 N-80 6.276" 2,172' 8,192' 7" 29 N-80 6.184" 8,192' 10,695' 7" 29 P-110 6.184" 10,695' 11,620' Tubing Detail Cplg OD 3.5" EUE 8RD 9.3 1 L-80 1 2.992" Surface 10,701' } ,. > . i ;;t 4.500" Milled K H-7 retainer to H-10 11,077' 9 Hemlock 10 A 7" _ Hemlock 11,620 TD = 12,046' PBTD =11,077' Downhole Revised: 5/31/14 Jewelry Detail No. Depth ID CID Item 1 17' 2.992" 6.184" Tubing Hanger w/ 8RD Box Down (8RD Pin Up on Full A Below) 2 51853' 2.992" 5.313" Gaslift Mandrel, Camco MM, Live Valve 3 7,974' 2.992" 5.313" 1 Gaslift Mandrel, Camco MM, Live Valve 4 10,600' 2.992" 5.313" Gaslift Mandrel, Camco MM, No Valve 5 10,701' - 4.000" Top of ESP, Discharge Head 6 10,788' - 4.000" ESPlntake 7 10,788' 4.950" 5.500" ESP Shroud (31' of 5-1/2" 15.5# Casing) 8 10,820' - 5.520" Base of ESP, 456 series Motor/ 400 series Pumps 9 11,077' - - Lost 7 ea %" SS bands (5.8" GR tagged on bottom 11/16/13) 10 11,077' - - Cement Retainer, Capped w/ 10 sx cement Cable/Clamp/Band Detail 10,800'- 10,820' - 8 ea 4560 Cannon Clamps (Across Motor Only) 10,701'- 10,800' - 18 ea 4010 Cannon Clamps (Across Pumps/Poseidon Gas Handler/Protector) 10,671'- 10,701' - 9 ea %" SS bands (all on 15` joint above discharge head) 0'- 10,671' - 3 ea %" SS bands per tubingjoint (additional 1 ea for flatpack every otherjoint) (Total of 1184 SS bands) 0'- 10,680' - 1 ea Reda #1 Round ESP Cable (Splices at approx. 35', 159', 5,912', and 10,680') 10,680'- 10,800' - 1 ea MLE Flat Cable (Splice depth at approx.. 10,680') 0'- 10,702' - 1 ea Dual Flatpack Encapsulated Control Lines (2 ea Chem Inj) 10,702' -10,820' - 1 ea Tri Flatpack Encapsulated Control Lines (2 ea Chem Inj, 1 ea Phoenix) Perforation History Date Zone Top(MD) Btm(MD) Top(MD) Btm(MD) Amt spf Comments 12/11/58 wso 10,795' 10,796' 10,795' 10,796' 1' 4 12/14/58 H-4 10,804' 10,836' 10,804' 10,836' 32' 4 Squeezed 12/14/58 H-5 10,849' 10,878' 10,849' 10,878' 29' 4 Squeezed 12/11/58 wso 10,880' 10,881' 10,880' 10,881' 1' 4 8/31/2012 H-6 10,906' 10,916' 10,906' 10,916' 10' 6 2.5" Owen 8/31/2012 H-7 10,926' 10,948' 10,926' 10,948' 22' 6 2.5" Owen 12/09/58 Hemlock 11,038' 11,060' 11,038' 11,060' 22' 4 Open 8/31/2012 H-10 11,050' 11,076' 11,050' 11,076' 26' 6 2.5" Owen 12/07/58 Hemlock 11,185' 11,195' 11,185' 11,195' 10' 4 Isolated Revised By STP 7/11/14 Hilcorp Alaska, LLC 20" tea; 22' -t T 13-3/8 1,490' CBLTOC 9,140' RKB: 272'/ GL: 257' AMSL KB -THF: 15.0' PROPOSED SCHEMATIC Casing Detail Swanson River Unit Well: SRU 331-27 Completion Ran: 11/19/2013 PTD: 100-148 API: 50-133-10156-00 Size Type Wt Grade ID Top Btm Hole Cmt Cmt Top 20" Conductor - - - Surf 22' - unknown Surf. 13-%" Surface 54.5 J-55 12.615" Surf 1,490' 18-%" 1,500 sx Surf. 1,497' 7" Prod Csg 29 P-110 6.184" Surf 1,027' 12 /.' 2,725' 1,000 sx 9,140' CBL 7" 29 N-80 6.184" 1,027' 2,172' 10-%" 11,659' 7" 26 N-80 6.276" 2,172' 8,192' 7" 29 N-80 6.184" 8,192' 10,695' 7" 29 P-110 6.184" 10,695' 11,620' Tubing Detail Cplg OD 11,060' 22' i 1CLU Jewelry Detail No. Depth ID OD Item 1 7,000' - Bridge Plug (Set for whipstock) 2 10,775' - Cement Retainer 3 11,077' - - Lost 7 ea %" SS bands (5.8" GR tagged on bottom 11/16/13) 4 11,077' - - Cement Retainer, Capped w/ 10 sx cement i n 2 '* Wso Top(MD) Btm(MD) Top(MD) H-4 y , "6- H-5 Comments 12/11/58 WSO WSO 10,796' H-6 10,796' 1' 4 Milled K retainer to H-10 11,077' 3 c9 Hemlock 4 7" Hemlock 11,620' '",J4,►:�i TD = 12,046' PBTD = 11,077' Downhole Proposed 3 Perforation History Date Zone Top(MD) Btm(MD) Top(MD) Btm(MD) Amt spf Comments 12/11/58 WSO 10,795' 10,796' 10,795' 10,796' 1' 4 12/14/58 H-4 10,804' 10,836' 10,804' 10,836' 32' 4 Squeezed 12/14/58 H-5 10,849' 10,878' 10,849' 10,878' 29' 4 Squeezed 12/11/58 WSO 10,880' 10,881' 10,880' 10,881' 1' 4 8/31/2012 H-6 10,906' 10,916' 10,906' 10,916' 10' 6 2.5" Owen 8/31/2012 H-7 10,926' 10,948' 10,926' 10,948' 22' 6 2.5" Owen 12/09/58 Hemlock 11,038' 11,060' 11,038' 11,060' 22' 4 Open 8/31/2012 H-10 11,050' 11,076' 11,050' 11,076' 26' 6 2.5" Owen 12/07/58 Hemlock 11,185' 11,195' 11,185' 11,195' 1 10' 4 Isolated Revised By STP 7/11/14 Swanson River 2014 Moncla Rig 401 Knight Oil Tools BOP CAMERON 3.68' p� 2 3/8-3'/: variable Sundry Application Plug for Re -drill Wells Work Flow This process is used to identify wells that are suspended for a very short time prior to being re -drilled. Those wells that are not re -drilled immediately are identified every 6 months and assigned a current status of "Suspended." Step Task Responsible 1 The initial reviewer will check to ensure that the "Plug for Redrill" box in the Patricia or Steve upper left corner of Form 10-403 is checked. If the "Abandon" or "Suspend" boxes are also checked, cross out that erroneous entry and initial it on both copies of the Form 10-403 (AOGCC's and operator's copies). 2 If the "Abandon" box is checked in Box 15 (Well Status after proposed Patricia or Steve work) the initial reviewer will cross out that erroneous entry and initial it on both copies of the Form 10-403 (AOGCC's and operator's copies). Instead, then check the "Suspended" box and initial that change. Guy or Victoria The drilling engineers will serve as quality control for steps 1 and 2. (QC) 3 When the Stat Tech receives a Form 10-403 with a check in the "Plug for Jenni Redrill" box, she will enter the Typ_Work code "IPBRD" into the History tab for the well in RBDMS. This code automatically generates a comment in the well history that states "Intent: Plug for Redrill" 4 When the Stat Tech receives any Form 10-407, she will check the History tab Jenni in RBDMS for the "Intent: Plug for Redrill" code (IPBRD). If present and there is no evidence that a subsequent re -drill has been COMPLETED, the Stat Tech will assign a status of SUSPENDED to the well bore in RBDMS no matter what status is listed on the 10-407. The Stat Tech will also change the status on the 10-407 form to SUSPENDED, and date and initial this change. If the Stat Tech does not see the "Intent: Plug for Redrill" comment or code, she will enter the status listed on the Form 10-407 into RBDMS. 5 When the Form 10-407 for the redrill is received, the Stat Tech will change Jenni the original well's status from SUSPENDED to ABANDONED. 6 The first week of every January and July, the Stat Tech and one of the Jenni Geologists will check the "Well by Type Work Outstanding" user query in Patricia or Steve RBDMS to ensure that all of the Plug for Redrill wells have been handled properly. At this same time, they will also review the list of suspended wells for accuracy. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 RECEIVED JUL 11 2014 errs' -712/ % 19-- 1. Type of Request: Abandon ❑ Plug for Redril 0 ' Perforate New Pod ❑ Repair Well❑ Change Approved Program ❑ Suspend ❑ Plug Perforations ❑ Perforate ❑ Pull Tubing[—] Time Extension ❑ Operations ShutdovA ❑ Re-enter Susp. Wel ❑ Stimulate ❑ Alter Casing❑ Other. 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number Hilcorp Alaska, LLC Exploratory ❑ Development M • Stratigraphic ❑ Service ❑ 100-148 3. Address: 3800 Centerpoint Drive, Suite 100 6. API Number. Anchorage, Alaska 99503 50-133-10156-00 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? CO 123B Will planned perforations require a spacing exception? Yes ❑ No Swanson River Unit (SRU) 331-27 9. Property Designation (Lease Number): 10. Field/Pool(s): FEDA028406 Swanson River Field / Hemlock Oil 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): 12,046 12,046 11,077 11,077 11,077' N/A Casing Length Size MD TVD Burst Collapse Structural Conductor 22' 20" 22' 22' Surface 1,490' 13-3/8" 1,490' 1,490' 2,730 psi 1,130 psi Intermediate Production 11,620' 17" 11,620' 11,620' 7,240 psi 5,410 psi Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): See Attached Schematic See Attached Schematic 3-1/2'. 9.3# / L-80 10,701' Packers and SSSV Type: Packers and SSSV MD (t) and TVD (ft): N/A; N/A WA; N/A 12. Attachments: Description Summary of Proposal ❑✓ 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch n Exploratory n Stratigraphic❑ Development n Service n 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: 07/21/14 Oil��, Gas ❑ WDSPL ❑ rSuspended 0 _A WINJ ❑ GINJ ❑ WAG ❑ Abandoned ❑ 16. Verbal Approval: Date: Commission Representative: GSTOR ❑ SPLUG ❑ 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Cortact Stan Porhola Phone: 907-777-8412 Email S orhola hllcor .corn Printed Name Stan Porhola� Title Operations Engineer /J Signature C" Phone 907-777-8412 Date h COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Z ` Plug Integrity ❑ BOP Test Z Mechanical Integrity Test ❑ Location Clearance ❑ Other: d0 C' >, f i t ( , �� t Spacing Exception Required? Yes ❑ No [q Subsequent Form Required: _ APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: r � Form 10-403 (Revised 10/ 2) RQCMS JUL 2 2 21JI 7-1 � - h OftfiGsN*Loriths Approvfrom the date of approval. '00Q, /71/17111 Submit Form and Attachments in Duplicate --," / ,.1/ (- o>r r • THE STATE Department of Environmental 011-1LASKL'1 GOVERNOR SEAN PARNELL RECEIVED FEB 0 7 2014 February 4, 2014 A0GCC Certified Mail, Return Receipt Requested Article No.: 7012 2210 0002 1216 2391 Wayne Svejnoha BLM — Division of Resources 222 W 7th Ave, #13 Anchorage, Alaska 99513 Conservation Division of Spill Prevention and Response Contaminated Sites Program File: 320.38.010 SCANNED 0 2 2014 Re: Potentiall Responsible Party Notice Letter and Information Request NPRA Legacy Wells - General Hazard ID: 26125 Ledger Code: 14339387 Dear Mr. Svejnoha: 610 University Ave. Fairbanks, Alaska 99709-3643 Main: 907.451.2181 Fax: 907.451.5105 This letter is to advise you that the Alaska Department of Environmental Conservation (ADEC) has identified the 136 legacy wells within the National Petroleum Reserve in Alaska (NPRA) as potential contaminated sites. Some of these wells require extensive cleanup of oil and other hazardous substances released to the environment. Since you are identified as a current or past owner and/or operator of these sites, please be advised you may be financially responsible or liable for the investigation and /or cleanup of any hazardous substance contamination that might be present. Alaska Statute 46.03.822 establishes who is liable for contamination. Records available to the ADEC indicate that you meet one or more of the following criteria: » owned or controlled the hazardous substance at the time of its release; » own(ed) or operate(d) the property or facility from which the release occurred; » owned or operated property at which the hazardous substance came to be located; and » arranged for transport, disposal or treatment of hazardous substances that were released. Site History From 1944 through 1982 the US Government drilled 136 wells to explore for oil and gas resources in the NPRA. It is our understanding that other federal agencies and some private companies may have operated or managed these sites in the past. We have also been informed that 23 of these well have been conveyed to public and private entities. The ADEC currently lists 14 of the 136 legacy wells on our database of contaminated sites. The Bureau of Land Management (BLM) is identified as the responsible party for the following sites. Wayne Svejnoha 0 2 February 4, 2014 • BLM Cape Halkett Drill Site (File # 300.38.108) • BLM East Simpson #2 (File # 300.38.109) • BLM East Teshekpuk Drill Site (File # 300.38.110) The U.S. Army Corps of Engineers, under the Formerly Used Defense Sites program, is working with ADEC under the Defense States Memorandum of Agreement on cleanup actions at the 11 Umiat test well sites. BLM is identified as the landowner in our records, and as such is identified as a potentially responsible party in addition to the Department of Defense: C Umiat Test Wells 1-11 (File # 335.38.001) The information contained in these files is part of the public record. Our databases are accessible on the Internet at: http://dec.alaska.gov/spar/csp/db_search.httn Additional Actions Needed ADEC sent a letter on July 11, 2013, identifying an additional 15 legacy well sites with confirmed releases (enclosed). As stated in the letter, ADEC recommends that BLM develop a plan to address known, suspected, and unknown releases at the legacy well sites, in coordination with the appropriate regulatory agencies. We expected a response to this letter before now. Please respond to this letter within 30 days. After we receive and review your response we will determine what additional actions will be taken regarding each site with known or suspected contamination. In addition, with your response, please complete and return the enclosed questionnaire requesting more information about past operators. In accordance with Alaska Statute Title 46, ADEC is authorized to provide regulatory oversight for any contamination response efforts initiated by the responsible party. However, if response actions by the responsible party are not satisfactory to ADEC, we may then assume the lead role in the investigation and cleanup efforts. In the event that State response actions are necessary, the responsible parties may be held financially liable for any response actions taken by the State. Alaska Statutes 46.04.010 and 46.08.070 establish cost recovery procedures for certain costs, including oversight activities, incurred by the State in responding to pollution incidents. If you are determined to be a responsible or liable party, ADEC may bill you at a later date for our expenditures associated with this pollution incident. Expenses for which we may seek reimbursement include: Staff time associated with general or technical assistance; work plan review; project oversight; general project management; legal services; interest; travel; equipment and supplies; and any contracting costs. Pursuant to Alaska Statute 46.08.075, the State may also file liens against all property owned by a person who is responsible or liable for State expenditures. Please respond in writing within thirty (30) days from the date of this letter addressing your intended actions with respect to this pollution incident. If you believe someone else is responsible for this pollution incident (e.g., a past owner or operation of the site) or if you have any questions concerning this matter, please contact Mr. Fred Vreeman at (907) 451-2181. The attached "ADEC Information Request" describes the minimum information expected in your response. Additional information may needed to evaluate the risks and responses required at each legacy well site. Sincerely, Fred Vreeman Environmental Program Manager G:\SPAR\CS\Contaminated Site Files (38)\320 National Petro Reserve Area\320.38.010 NPRA Legacy Wells General\2-2-2014 Letter\PRP Letter All Wells.docx Wayne Sveinoha Enclosure: 0 3 • ADEC Information Request Concerning Contaminated Sites BLM Legacy Wells Dispute letter date July 11, 2013 February 4, 2014 cc: Bud Cribley, Director, Bureau of Land Management Steven Cohn, Deputy Director, Bureau of Land Management Jolie Pollet, Branch Chief, Bureau of Land Management Robert Brumbaugh, Geologist, Bureau of Land Management Michael McCrum, Environmental Engineer, Bureau of Land Management Larry Hartig, Commissioner, Alaska Department of Environmental Conservation Lynn Kent, Deputy Commissioner, Alaska Department of Environmental Conservation Kristen Ryan, Director, Alaska Department of Environmental Conservation Lori Aldrich, Program Manager, Alaska Department of Environmental Conservation Steve Bainbridge, Program Manager, Alaska Department of Environmental Conservation Jennifer Roberts, Program Manager, Alaska Department of Environmental Conservation ADEC Response Fund Administration GASPAR\CS\Contarr nmted Site Files (38)\320 National Petro Reserve Area\320.38.010 NPRA Legacy Wells General\2-2-2014 Letter\PRP Letter All Wells.docx 0 0 ADEC INFORMATION REQUEST Concerning a contaminated site(s) Re: Legacy Well Sites in and near the National Petroleum Reserve, Alaska (NPRA) Please precede each answer with the number of the question to which it corresponds. Please direct any questions concerning this information request to Fred Vreeman, Contaminated Sites Program, 610 University Avenue, Fairbanks, AK 99709; Phone: 907-451-2181. Thank you for your cooperation. 1. Provide name and company affiliation of the person answering the questionnaire. 2. Provide copies of all studies, reports, and supporting information (including preaquisition assessments and work done on behalf of other parties) which you have knowledge of which address past and/or present environmental conditions at the site. Identify the name, title, address, and phone number of the party(s) who are responsible for preparing the studies or information. Information which has been previously submitted to ADEC need not be submitted again (unless specifically requested in a subsequent communication) if you can provide the name of the office (and name and title of the DEC officer if known) to whom the report was previously provided. 3. Provide a description of any ongoing or planned investigations or cleanup work at the site. Identify the names, titles and phone numbers of the individuals responsible for preparing the studies or information. 4. Provide a description of known releases at the site (date of occurrence, quantity released, type of substance released, etc.) and a description of corrective measures that were taken. Provide information on any suspected releases which may have or are occurring. 5. Describe the nature of past and present operations at the site. In particular, any actions that may have caused the release or threat of release at the site. Describe the physical characteristics of the site including major structures, water wells, fuel or waste storage systems, drainage or septic systems, etc. 6. Provide a list of any permits issued by the Department which relate to activities at the site and a list of RCRA identification numbers (U.S. EPA identification numbers) which may be held. 7. Identify persons to whom you leased all or a portion of the property and describe the nature of their operations. 8. Identify the person(s) who used the site for disposal of substances deposited there, if any. 9. Provide copies of manifests for any hazardous waste and/or petroleum contaminated materials taken to or from the site. 10. Provide a list of persons and their phone numbers and addresses of persons who have knowledge about the use of hazardous substances at the site. 11. Provide information regarding the existence of insurance coverage for damages resulting from releases of hazardous substances and copies of all such insurance policies, both currently in effect and in effect during the periods of activity in question. 12. Describe the acts or omissions of any person, other than your employees, agents, or those persons with whom you had a contractual relationship, that may have caused the release or threat of release of hazardous substances at the site. a. In addition, describe all precautions that you took against foreseeable acts or omissions of any such third parties. 13. Describe the care you exercised with respect to the hazardous substances found at the site. 14. Describe the physical characteristics of the site including structures, wells, drainage systems, etc. THE STATE July 11, 2013 'ALASKA GOVERNOR SEAN PARNELL Wayne Svejnoha Supervisory Minerals & Energy Specialist 222 W 7th Avenue, #13 Anchorage, Alaska 99513 Re: BLM Legacy Wells Dispute Dear Mr. Svejnoha: Department of Environmental Conservation Division of Spill Prevention and Response Contaminated Sites Program 610 University Ave. Fairbanks, Alaska 99709-3643 Main: 907.451.2181 Fax: 907.451.2155 The Alaska Department of Environmental Conservation (ADEC) — Contaminated Sites has reviewed the National Petroleum Reserve in Alaska: 2013 Legacy Wells Summary Report dated February 2013, containing updated information on the status of the 136 Legacy Wells located in the National Petroleum Reserve — Alaska (NPR -A), and the draft National Petroleum Reserve in Alaslm. 2013 Legacy Weiss Strategic Plan dated May 2013. ADEC has also reviewed the response by the Alaska Oil and Gas Conservation Commission (AOGC). We concur with the response by ACIGC and have no further comment regarding the priorities. We do have comments about the investigation and cleanup plans presented in the report. With this letter we arc outlining regulatory requirements related to the environmental work that is proposed and required as part of these cleanups. ADEC is concerned that the 2013 Legacy Wells Strategic Plan prepared by the BLM does not include either assessment of the contingency for assessment of known, likely, or unknown but possible contaminant releases. In addition, BLM plans for surface cleanup of these wells should be made clear in the plan. At least one of these legacy wells has extensive PCB contamination and has resulted in a multi-year cleanup totaling tens of millions of dollars. At others, solid waste disposal practices have resulted in releases to the environment with estimated cleanup costs in the hundreds of millions. Known releases documented in the records we reviewed include crude oil, gasses, refined oil and fuel, drilling fluids that include various organics, metals, and other chemicals, and unknown contaminants from drums and other containers observed to be damaged and abandoned at the various well sites. There are 13 legacy well sites with known releases currently on the DEC contaminated sites list. Many of these are in the process of being addressed, cleaned up, and closed. From our Waited records review there are 15 additional legacy well sites with confirmed releases. These should be prioritized for initial records reviews and then added to the BLM contaminated sites list under our cooperative agreement. Suspected releases include fuel releases from operations, storage, and fuel spills at the sites, impacts to various surface water bodies from spilled fluids during drilling and breaches of containment at reserve and flare pits, continued surface runoff from drilling fluids uncontained at several sites, and down -hole substances that were ejected from the holes over time or during blowouts or drilling operations. 1 Wayne Sve noha ? July 11, 2013 Y The.BLN-1 plan to address these known, suspected, and unknown releases at legacy well sites is notably absent from the documents presented to date. The three primary regulatory agencies that need to be involved in the plan are ADEC — Contaminated Sites, Alaska Oil & Gas Conservation Commission, and ADEC — EH/Solid Waste. Other agencies will need to be consulted. as well. Below we provide recommendations for a coordinated plan using the Uniform Federal Policy for Quality Assurance Project Plans (UFP-QAPP) that will involve all of the regulatory agencies in one coordinated manner. This will allow BLM to address these sites in a consistent and coordinated project which fulfills all of the regulatory requirements so that the sites do not need to be re -visited in the fu=e xvhen they are closed after this project. Attached are our comments on each specific well. The acronyms used on the list include terms that are typically used in a CERCLA type investigation however they are also suitable for investigations conducted under the State of Alaska cleanup rules. These include the following; Historical Records Review (HRR) 'chis is recommended for almost all of the well sites. Much of the information required for these reviews is already contained in various reports and appendices or in BLM files. The Historical Records Review should document the type of releases that might have occurred from drilling operations as well as historical use of the site, and should capture all available information on the drilling fluids used and any product produced or released. Preliminary Assessment (PA) This is recommended for almost all of the well sites. A Preliminary Assessment is a limited scope investigation that provides an assessment of information about a site and its surrounding area to distinguish between sites that pose little or no threat to human health or the environment and sites that require further investigation. The PA is a CERCLA defined document and typically does not require sampling. Site Inspection (SI) If the PA recommends further investigation, then an SI is necessary. The SI is a CERCLA defined document, and it is analogous to an initial report of contamination under state cleanup rules. On some legacy well drillings sites it is evident now that an Sl is required just from a review of the reports. An SI investigation typically includes the collection of samples to determine what contaminants are present at the site and whether they are being released into the environment. An approved site specific workplan is required under both CERCL-A and 18 AAC 75 prior to SI sampling. The SI typically is not intended to develop a full site characterization, but is limited to determining the presence or absence of a release. If contamination is found after completion of the HRR, PA, and SI then a RI/FS under CERCLA, or a Site Characte-rizatiowlteportandcleanup-Alas,under-l-fi-AAC7iis`required. -- ----- - -- — --------- - DEC recommends that BLM incorporate into the strategic pian the processes outlined in this letter. A team of agencies composed of AOGC, DEC -CS, EPA as required, and DEC -EH should address regulatory and technical requirements for these well closures. By cooperating and working together with the regulatory agencies BLM will save time and expense, and regulatory uncertainties will be avoided. The strategic plan should reference a project to prepare a generic workplan. DEC suggests that BLM utilize the generic UFP-QAPP workplan format for the required environmental work. If properly prepared, the workplan could encompass most of the investigations and cleanups required at these sites over multiple years. At other multi -site projects we have found this to be an effective way to reduce uncertainties and risk in these types of investigations. A very small site specific FSP could then be developed as BLM approaches each drilling site. Regulatory decisions made during workplan development would provide more certainty in the planning process for cleanups. G:\SPAR\CS\federal F2cilitie3\Ci%ih2n 1-cdcrrt Agr=ics\DOl\B[.nl\1'roiens\lxgAey Wells\7 11 13 Luter to KIN on lxbxy wells.doex Wayne Svejnoha 3 0 July 11, 2013 Please review the attached list of specific sites. If you have any questions, please do not hesitate to call me at 907-451-2181 or by email at fred.vreeman@alaska.gov. I look forward to working with you as the Federal Government fulfills its requirement to clean up these well drilling sites in Alaska. Sincerely, y' Fred Vreeman Environmental Program Manager Enclosure: SPAR Response with Legacy Wells cc: Bud Cribley, State Director, Bureau of Land Management Steven Cohn, Deputy State Director for Resources, Bureau of Land Management Jolie Pollet, Branch Chief, Bureau of Land Management Robert Brumbaugh, Geologist, Bureau of Land Management Michael McCrum, Environmental Engineer, Bureau of Land Management Cathy Foerster, Commissioner, Alaska Oil and Gas Conservation Commission Larry Hartig, Commissioner, Alaska Department of Environmental Conservation Kristen Ryan, Director, ADEC Division of Spill Prevention and Response Steve Bainbridge, Program Manager, ADEC Contaminated Sites Program Jennifer Roberts, Program Manager, ADEC Contaminated Sites Program GASI'AR\CS\Fedcrrl Fo61ibLy\Gvi6n Falctul AgcnnCs\DOI\BI.N1\Proitcts\lA'6.1' q W03\7 11 1314tur to Aim\I on Ug2cy Wclls.doex Well Name operator I RP I Land Simpson Core Test #5 1! Na 1 BLM Simpson Core Test #6 US Na I BLM Simpson Core Test #7 us Na 1 Bl. M Sin son Core Test 98 US Navy 113LM Si son Core Test #9 U5 Na I BLM Sinwson Core Test #1f) U.S Navy! BLM Core Test #11 AOGCC Subsurlaca I BLM Core Test #12 FUSNa a I BLM Core Test #16 a 18LM Core Test #17 US Na 1 BLM Core Test 018 US Na I BLM Core Test #19 US Na 1 BLM t Core Test #20 US Navy 1 BLM i Gore Test #21 2S Na 1 BLM I Core Test #22 US Na 111•LM I Core Test dnlf fluids left in hole i BLM Core Test �#2vy I BLhA n CareTest #25 US Na Y I BLM K Core #1 US Navy i BLM 1 -t- *1 SPAR Response with Legacy Wells Lisl.xlsx 2013 Risk Ity CSP Status I Fito tllHazid Rolea5e7 Nnne None IYOMWil Low RNooe ane Nona Unused, Unused. I None Unused, i None Uncased, None None None None (None Unknown Unknown Page 1 of 14 •I AOGCC Subsurlaca AOGCC Surface SPAR W arkgroup Notes Status Status Need HRR, PA, S1 no data no data Need HRR. PA. SI no data no data Need PA ind drill fluid assessnsenl & workplan drillin 11uids left in hole no data Need PA ind drill fluid assessment & work an drilling fluids left in hole no data Need PA incl drill Ifusd assessment & work Ian dnlf fluids left in hole no data Need PA nc drill fluid assessmcnf &work Ian dnllxs fluids left rn hale no data well skc-lch provided by Need PA ind drill fluid BLM not consistent with assessment & work Ian AOGCC or BLM data no data Need PA ind drill fluid assessment & work Ian dnflin fluids left in hole no data Need PA and 51 ind 13611 fluid assessment. workplan rid sampling stressed debfis, partially as blowout and fire rove elated site areas Need PA incl drill fluid assessment & workplan dn lling fluids left in hole no data geed PA ind drill fluid assessment & wOTk Ian drij I ing fluids teff in hole no data Need PA incl dfifl nutd assessment & work Ian drillin fluids left m holo no data Need PA incl drill fluid assessment & work Ian drillin ituids left in hole no data Need HRR. PA, SI no data no data Need PA incl drill fluid assessment & work Ian drillin fluids felt in hole ria data Need PA incl dnll fluid assessment & work larx drillin fluids left in hole no data Need PA incl drill fluid assessment & work Ian drillin fluids Teff in hole no data Need PA ind dnll fluid drflfing fluids and ball assessment & work len peen hammer left in hole no data overshot, drill collar, rock revegelated —131 Need HRR, PA bit, and N -reds left in hole can't find it Review Report as PA. No evidence of sheen, stressed veg, or drilling Not abandoned, waste on surface. Veg ----_— , ,raw,, plunaed to surface site not cleared •I SPAR Response with Legacy Wells LisLxlsx Page 2 of 14 is • vi nce o BLM 2013 Risk Historic AOGCC Subsurface AOGCC Surface Well Name Operator I RP I Land Mgr Priority CSP Status file #IHazid Release? SPAR Workgroup Notes Status Status plugging operations inadequate and Wellhead tell as Umiat 43 US Navy I BLM I FUDS None pending dos 335.38.00113092 Yes. see file 'Plugged by BLM in 2004 incomplete historic site? plugging operations inadequate and Wellhead left as Umiat #4 US Navy I BLM / FUDS None pending dos 335.38.001!3079 Yes, see file Plugged by BLM in 2004 incomplete historic site? plugging operations inadequate and Wellhead left as Umial 98 US NaMy I BLM I FUDS None pendinq dos 335.38.001/3D81 'Yes, see_ _file Plugged BLM in 2004 incomplete historic sile? plugging operations inadequate and Wellhead left as Umiat #1'0 US Navyj BLM_I FUDS None pendingdos 335.38.00113082 Yes, see fila Plu ed by BLM in 2004 incomplete historic site? Need HRR, PA, SI with sampling. Drilling mud assessment. Surface Plugged to 7868'. Drilling Cleanup. Photos - evidence mud and diesel to Awuna #1 USGS I BLM Medium None None Yes of erosion into lake surface. > 100 _Pylons Need HRR, PA, SI with sampling. Drilling mud Wood , metal, assessment. Surface Plugged to 2039'. Diesel plastic debris. Fast Simpson #1 USGS I BLM Low None None Yes Cleanup. to surface. >10D Pylons Need HRR, PA, SI with Wood and metal Drilling mud assessment debris. Pylons - Photos straw areas of no Plugged to 2047'. Diesel Tankage for lk ' #1 USGS / 8LM Low None None Yes ve elation. to surface. flammable fluids Need HRR. PA, SI wdh sampling. Drilling mud assessment. Surface Plugged to 1400'. Drilling Wood and metal Koluktak #1 USGS I BLM Low None None LYes Cleanup. mud & diesel to surface debris Pylons Need HRR, PA, SI with sampling. Drilling mud assessment. Surface Plugged to 1894'. Diesel Wood and metal Ku am 91 USGS I BLM Low None None Unknown Cleanup. to surface debris. Pylons Need HRR, PA, Sl with sampling_ Drilling mud assessment_ Surface Plugged to 4464'. Drilling Wood & metal Kuyanak #1 USGS I BLM Low None None Yes Clean mud & diesel to surface debris. Pylons Need HRR, PA, SI with sampling. Drilling mud assessment. Surface Cleanup. Photos show Plugged to 1840'. Diesel Plastic and metal Lisburne 41 USGS I BLM Low None None Yes stained soil to surface debris. Need HRR, PA, SI with sampling. Drilling mud assessment. Surface Plugged to 8192'. Drilling Wood and metal North Iii ok $1 USGS I BLM Low None INone Yes Cleanup. mud & diesel to surface debris - Page 2 of 14 is • Well Name Peard South Meade #1 1 RP 1 Land 1BLM BLM #1 4USGS ! BLM SPAR Response with Legacy Wells Usl.xlsx ;013 Risk &W CSP Status File XlHazkl T Page 3 of 14 AOGCC Subsurface AOGCC Surface WAR Workgroup Notes Status r Status � deed HERR, PA SI with iampling. Dining mud rssessment- Surface ;leanup. Site photos show areas of stressed iegetalion. No issues Plugged to 2232'. Diesel Wood and metal soled in USGS re ort. to surface debris. Pylons Need HRR, PA, SI with sampling_ Drilling mud assessment Surface Plugged to 2026'. Diesel Wood and metal Cleanup. to surface debris. P Ions Add to She list. Need HRR, PA, SI with sampling. Drilling mud assessment. Surface Cleanup. Od reported bubbling to the surface within reserve pit in 1982. Oily residue and sheen observed adjacent to east side of reserve pil, down hole material at the Plugged to 1875. Diesel Wood and metal surface to surface debris. P ons Add to Site list. Need HRR, PA, S) with sampl'uig. Drilling mud assessment - Surface Cleanup. Reserve pit berm had breaches anowirrg water to exit. Oil - stained sediment was observed above the Plugged to 1478'. Diesel Wood and metal waterline of the I. to surface debris. Site photos may show hydrocarbon sheen on Plugged to 2600'. Drilling Wood and metal water in well cellar mud & diesel to surface debris. Pylons Add to Site list. Need HRR, PA, SI with sampling. Drilling mud assessment. Surface Cleanup. Berms have been breached an allow water to flow out of reserve piUllare pit. Rising bubbles of ail observed in Hare pit 1484. Photos Show Plugged to 1825'. Diesel Metal debris. ra.. v-1 v.nnnralinn to Surface ... 0 •I SPAR Response with Legacy Wells Lisl.xlsx Page 4 of 114 0 0 vi encs o BLM 2013 Risk Historic AOGCC Subsurface AOGCC Surface Well Name Operator 1 RP f Land Mgr Priority CSP Status File #fHazld Release? SPAR Workgroup Motes Status Status Need HRR, PA, Sl wrlh sampling. Drilling mud assessment Surface Cleanup. Breaches in bemi allow water to flow into and out of reserve pit, sheen on Plugged to 2700' Diesel Wood and metal West Dease #1 USGS l BLM Low Nona None Yes surface water in well cellar to surface debns. Pylons Add to Site list. Need HRR,. PA, SI with sampling. Drilling mud assessment. Surface Cleanup. Water flows into the pits through breaches on the eastern berm and out of the pits through breaches on the northern and western berms. Downhole material Plugged to 228'9'. Drilling Wood and metal South Harrison Bay #1 USGS f BLAB Low None None es Present at surface mud & diesel to surface debris. Add to Site list. Need HRR, PA, SI with sampliing. Drilling mud assessment. Surface Cleanup. Stressed vegetation noted and apparent in site pholos. Plugged to 2443'. Drilling West Fish Creek #1 USGS 1 BLM Low None None Yes Drilling mud around well mud & diesel to surface Pylons Need HRR, PA, SI with sampling. Drilling mud assessment, Surface Cleanup. High TPH Plugged to 1977'_ Drilling wellhead sticking concentrations underneath mud under plugs. Diesel up. Wood debris. Fast Simpson #2 USGS 1 BLM I Low _ Active 300.38.10912691 Yes, see file the rig inundation to surface Pylons South Barrow 94 US NavyiNorth Slope Bono None None None Unknown Need Surface Status completed gas well - no data South Barrow #5 USAF - BLM Unknown None None None. Unknown Need Surface Status completed gas well no data South Barrow #& US Na /Norlh Sto Burg None None None Unknown Need HRR, PA, St no data no data South Barrow #9 US NavyfNarih Slop2 Boro None None None Unknown Need HRR, PA, Sl no data no data _ South Barrow #10 US Navyfflorlh Sto Bora None None None Unknown Need Surface Status com ted gas well no data South Barrow It12 US Na /North Slope Baro None None None Unknown Need HRR, PA. Sl no data no data BLM well skMh not consistent with AOGCC South Barrow #14 US NavyMorth Sloe Boro None None one Unknown Nsed HRR. PA, St data no data Need PA ind drill fluid well left filled with drilling South Barrow #16 US NavyiNotih Slope Bora None None None Unknown assessment & workplan mud and diesel no data Need PA incl drill !turd tubing in well. no perfs, Soulh Barrow 017 US Na /North Sloe 13ora None None None jUnknown assessment & work fan I unknown fluid, I no data Page 4 of 114 0 0 SPAR Response with Legacy Wells Lisl.xisx Page 5 of 14 •I E CYfuu .v v AOGCC Subsurface A Surlaco TEHILM T013 Risk CSP Stilus File #IHaaid Historic Rekeasa7 SFAR YUnrkgroup Nates 5latus at US $1<ntus Well Name flperatar f RP f Land Mgriority Unknown Need Surface Status corn feted as well no data 5aulh Barrow #18 US Na INorlh Slo a Bora None None None Unknown Need HRR, PA, St no data no data Walak a #1 USGS! Unknown None None None rsg 890`. Multiple cement plugs of unknown volume. Shallowest None None Unknown _ Need HRR, PA, SI SOD' no dada Gubik #1 US Na d Ur#cnown Low Add to Site list. Need HRR. PA. SI with sampling. csg Q SOD' Well blowout Drilling mud assessment. from zone al 1SOT during Surface Cleanup. Photos plugging operations show disturbed/ slashed Plugging never completed after blowout. no data Gub* #2 US Na ! Unknown Low None Nora es areas two downhole Dement plugs of unknown depth Mone None Unknown Need MR. PA. Sl and volume no data Grandstand #1 US Navy 1 Unknown None Add to Site list. Need HRR. PA, SI with sampling. Dnliing mud assessment. Surface Cleanup Sediment from the reserve pit was excavated and spread over the pad to drill a 2nd well at this location, Upon completion of the 2nd well. the sediment was pushed back into ft reserve pit.. Area does not appear to be revegetaling. perhaps from the presence property plugged but no of drilling mud at the data on abandonment None None Yes surface status no data W 7 Foran #1 " USGS I Unknown Low on Site list. Need HRR, PA, SI with sampling. Drilling mud assessment. Surface Cleanup. Slressed vegetation, photos show plugged, but not open csg; metal & Active 306.3$.108f2689 Yes. see file site underwater abandoned at surface corwsele debris under 5' of water, Cape Halken #1 " US Na (Unknown Low None Unknown !Need HRR, PA. SI es to 27' open C_s Min a Veloei #1 U5 Na f t3LM one None csg @ 31" 280' of drill pipe, drill collar, and Core Unknown Need HRR. PA, SL barrel left rn hole. rove etaled Ournalik Core #i US Na / BLM None -No obsery None !None Page 5 of 14 •I E SPAR Response with Legacy Wells Lisi.xlsx Page 6 of 14 • • WI F3nCe Q BLM 2013 Risk Historic AOGCC Subsurface ADGCC Surface Well Name Operator t RP I Land Mgr Priority CSP Status File #IHazid Release? SPAR Workgroup Notes Status Status Need HRR, PA, Workplan for St with Sampling. Drilling Mud Assessment. Surface Cleanup. Photos show debris, stressed No csg. 15' of drift pipe Oumalik Caro #2 US Navy 1 ULM Low None None yes ve elation and rock hit left in hole. no data Need HRR, PA, Workplan for Si with Sampling open csg & other Drillip) Mud Assessment. piping sticking out Surface Cleanup_ Reports of ground; wood, of debris, drilling muds on melat, conciele Oumalik Core 011 US Navy 1 BLM Low None None Yes surface (__q to 9', debris open csg sticking out of ground; wood & metal 0umalik Core #12 US Navy I BLM Low None None No Need HRR, PA, SI no data —__—debris _„ debris buried by landslide. Need HRR, PA, St, Well not no dala on Sentinel Hill #1 US Navy 1 BLM Low None None Unknown ap panent in site Rholos Csq to 3t1'. underwater status Need IQR, PA, SI. No evidence of sheen, open crag slightly stressed veg, or drilling above ground waste on surface. Veg 37' of csg, drilling fluids level; wood and S imp son Core Test #1 US Navy 1 BLM Low None None No appears healthy lett in hole metal debris Need HRR, PA, St. No evidence of sheen, stressed veg, or drilling waste on surface_ Veg 76'01 Csg, drilling fluids Simpson Core Test #2 US Navy I BLM Low None None No appears healthy left in hate no data Need HRR, PA, Sl. No evidence of sheen, stressed veg, or drilling waste an surface. Veg 61' of csg, drilling fluids Sim sun Core Test #3 US Navy I BLM Low None None No appears healthy left in hole no data Need HRR, PA, St. No evidence of sheen, stressed veg, ordrilling waste on surface. Veg --60' of crag, drilling fluids Sim eson Core Test #4 US Nayy t BLM Low Norse None No apecars healthy left in hole no data Need HRR, PA, St. No evidence of sheen, stressed veg, or drilling waste on surface. Veg csg cemented @25% open csg sticking Songsoncore Test #13 US Na 1 BLM Low None None No appears health dritin fluids IeR in hole_ out of round Need HRR, PA, SI. Vegetated, no evidence of crag cemented @2D'; open csg sticking Simpson Core Test #14 US Navy ! BLM Low None None No release. drillin fluids left in hole out of ground Page 6 of 14 • • SPAR Response with Legacy Wells Lisl.xlsx ism son Core Fest #26 t=vrdence or Medium AOGCC Subsur(aen ADGGC Surface 13LM 2013 Risk CSP Status File WHazid Historic Retease7 SPAR Wwkgroup Notes Status Status Well Name operator r RP 1 Land Mgr Priority Unko Need HRR, PA. SL US Na ! $LM open casing None Nave Vegetated. no ev4dence of cog set shallow; drilling slicking nut of Low No release- fluids left in hole round Simpson Core Teri #14a US Na !BLM Low None None & weilhead slick Need HRR. PA, SI crude nil left in hole open casing Need HIR, PA, Workplan Vegetated, no e+wdence of csg cemented 12181; slicking out of openregd ng No release. drillingfluid left in hole round Simoson Care Tesl #15 US Na !BLM Low None None d wooden Oellar, Need HRR, PP, SL Sate a9 r�110'. dolling fluids wood 8 metal ism son Core Fest #26 US Na ! BLM Medium None None res Sim sen Core Test 027 US Na J 13LM IJone None None Unko Sim son Gore Test #28 US Na ! $LM Low None Nave Yes clmnnnn Core Tesl #29 US Navy! BLM Low Norte No No Simpson Core Test 030 US Na 1 !BLM Core Test #30a JUS,Navy 1 BLM Low `None Prone n Gore Test #31 JUS Navy/ BLM None Page 7o(14 photos appear to show oil at surface, from a natural csg Q 350'. Completed in oil seep, seep, also drilling mud in oil well Open perfs. At 1welhead sticking sacks on the tundra one lime capable of up_ metal debris PI u ed b BLM in 2004. unassisled flow. and rustingbarrels 'Need HRR, PA, St. Site photos appear to show Oil csg cemented at surface, from a natural @i02;dnllutg fluids nn oily ground; csg seep- Plugged by BLM in including diesel and & weilhead slick vin 20014 crude nil left in hole out of ground Need HIR, PA, Workplan for Sl with Sampling- openregd ng ❑rilling Mud Assessment . out grouunnd in Surface Cleanup. Site d wooden Oellar, photos appear to show a p le of drilling mud about a9 r�110'. dolling fluids wood 8 metal 160 feel tram the welt tell in hole debris. Solid waste Need HRR, PA, Sl_ No evidence of sheen, stressed veg, or dri" waste on surface. Veg csg cemented at 1S2'; open csg. Wood a ears healthy dnknq fluids lett in hole and metal debris Need HRR, PA, SI. frilling mud at surface. but well is also in the middle of a large in oil seep; Open oil seep and surrounded by cog sticking up; pooled oil. Plugged by BLNI csg cemented A150'; wood & metal ser Holes in 20514- drillin fluids left in hole detail on oily ground; tog Need HRR. PA, Sl. Well is wellhead slick in the middle of a large oil seep and surrounded by csg cemented at 100% out of ground. pooled oil. Plugged by 131. dulling mud left in hole. wellhead leaking see noses in 2004 gas blowout at 423' gas Need HRR, PA, St. Leaky valve replaced in 2001, little evidence of contamination following valva on city ground; reg replacement- Plugged by csg cemented at 100'; & wellhead stick see notes BLM in 20174 iddifing fluids, left in hole out o1 round SPAR Response with Legacy Wells List.xlsx Page 8 of 14 • • yr enco o BLM 2013 Risk Historic AOGCC Subsurface AOGCC Surface Well Name Operator f RP f Land Mgr Priority CSP Status File glHasid Release? SPAR Workgroup Notes Status Status Need HRR PA, Workplan csg Cemente=d al for Sl with Sampling. 1028', cement plugs a1 Drilling Mud Assessment. 6387' and 5520'. Fish in Surface Cleanup. Drilling hole, drilling fluids Iefs in No data. Open Simpson Test Welt #1 ak US Navy1 BLM Low None INone yes muds near wellhead hale casing Need HRR, PA, Workplan for Sl with Sampling. Dolling Mud Assessment. Surface Cleanup Also Wellhead sticking evidence of a natural seep- above ground, Tar sheens in the summer ST from 2552 to 3018. wood, melel, and months. BLM is concerned csg @2915. Slotted liner concrete debris. Fish Creek #1 US Navy I BLM Medium None None Yes about exposure to wildlife to TO. Completed oil well Rusting barrels Need HRR, PA, Workplan for SI with Sampling. rasing cemented at 48; Drilling Mud Assessment. gas 0mv and explosion Surface Cleanup. Small gas while drilling at 863'; hole leak in wellhead flange, will Filled with fresh water to Wolf Creek 91 US Navy f BLM Low None Nano No flow if the valve iso en 330' No data. csg cemented a[ 53';hole left tilted with fresh water, Wolf Creek 02 US Navy 1 BLM Low Noire Nona No Need HRR. PA. Sl. fish in hole csg cemented at 107'; No data bridge plugs from 1447 to 1735 and from 554 to Wolf Creek #3 US Nayy I BLM Low None None No Meed HRR, PA, SI. 661, No data Add to Site list. Need HRR, PA, SI with sampling. csg slicking out of Drilling mud assessment ground with wood Surface Cleanup. Sheen on plug on top; solid surface water in well cellar, csg cemented at 30'; drill waste; wood hundreds of drums indicate pipe, drilling mud and debris; about 200 Skull Cliff Core iesl #1 US NaMy I BLM High None None Yes polential for cornlamrna[ion diesel left in hole nisling barrels Need HRR, PA, SI. Two open csg, wood drums are floating on a building; pylons; pond near the well. csg cemented at 1000', wood & metal Kaolak 01 US Navy 1 BLM t ow None jNone lNo Potential for hurried landfill. fdriltingluidsieftin hole debris Page 8 of 14 • • SPAR Response with Legacy Wells Lisl.xlsx 181-11119013 Risk Well Name Operator f RP ! land Mgr Priorlty CSP Status File 1NHazid #1 1 U Navy 19LM #1 JUS Navy/ umatik Ill US Na I BLM Low None None as[ Oumalik #i US Na !BLM Low None None #1 N East Topagoruk #1 USN l BLM Kniteblade #1 US Navy l BLM Page 9 of 14 Subsurface `AOGCC Surface SPAR Workgroup Notes Status Add to Site list. Need HRR, PA, SI with sampling. open flange Q Drilling mud assessment. Surface Cleanup. Drilling Gas well. Open ports. ground level. Mud pile overgrown with Drilling fluids and Metal & wood v , etallon and lichen tubulars lett in hole debris Need HRR, PA, SI. No evidence of sheen, stressed veg, or drilling csg cemented at 502'; open casing slicking out of waste on surface. Veg plug at 3470 to 3511'; ground. Wood appears heall drilling nuids left in hole debris. Open casing below Add to Site list. Need HRR, ground level. PA, SI with sampling- Revegetated. Drilling mud assessment. Numerous metal Surface Cleanup. Debris csg partially cemented at I support structures and drilling muds. Stressed 2762'. Plug at 2543% slicking up. vegetation Dridin mud left in hole Concrete debris, plate welded to pipe: l' of pipe rsg cemented at 1100'. sticking up - Need HRR. PA. SI. Drig fluids left in hole Wooden debris. Add to Site list. Need HRR, PA, SI with sampling. Driving mud assessment. open csg broken Surface Cleanup. Downhole material present csg cemented at 6073'. off and sticking up: at surface, area mostly original hole drilled to wood, metal, revegetated. Diesel still 7154'& junk len; concrete and other occupies the ground sidetrack hole left wilh debris. rusting dreulatioir lines. drillina fluids barrel Add to Site list. Need HRR, PA, SI with sampling. Dolling mud assessment. Surface Cleanup. Pile of tsg 10 1100'; pkig al open casing drilling muds is next to the 1049% drilling mud below sticking up. Wood, teller. No offical reserve pit plug: unknown fluids in metal, and glass noted o en hole debris. open casing Need HRR, PA, SI. BLM sticking up. Wood, stales that there was no metal, and glass debris at this site in 2012. csg cemented at 420% debris - •I 0 SPAR Response with Legacy Welts Lisl.xlsx Paye 10 of 14 0 0 w once a BLM 2013 Risk Historic AOGCC Subsurface AOGCC Surface Well Name Operator I RP f Land Mgr Priority CSP Status File #IHazid Release? SPAR Workgroup Notes Status v F Status open casing sticking up. Wood, metal, & concrete debris rusting Need NRR, PA, SI. Reports barrels. One indicate solid waste csg cemented to 45';fish marked flammable Knileblade #2 US Navy I BLM Low None None No drums in hole hazard. open casing slicking up; metal & Krideblade #2a US Navy 1 BLM Low None None No Need HRR, PA, SI. csq cemented at 38% concrete debris Need HRR, PA, SI including learning assessment. Site partially No wellhead. submerged intermittently csg cemented at 80; Metal. Solid waste North Simpson Test Wel 4 US N2n I BLM Low None None No during the summer dri0ing fluids left in hole ? No dala crude wellhead. Need HRR, PA, St. Surface csg cemented at 685'; Wood and metal Umiat 01 US Navy J BLM I FUDS Medium Cleanup co 335.38.00113090 Yes, see file Cleanup drillinq fluids left in bole debris No wellhead. Gravel pad partially csg cemented a1486; revegelaled wood Need HRR, PA, SI. Surface cement plug from 440 to debris and pipe Umiat #i t US Na I BLM I FURS Low pending dos 335.38.00113083 Yes, see file Clea 490'; sticking u csg cemented at 7206'; vVefNwad- Gravel various plugs from 8250' pad revegetaled 7 South Sirnpson 01 US Navy I BLM Low None None Yes Need HRR, PA, SI. to surface No data Add to Site list. Need HRR, PA, SI with sampling. Drilling mud assessment. Surface Cleanup. Large quantifies of ferrous oxide, zinc oxide, zinc carbonate, and barium sulfate were added to drilling muds. Stains apparent in photos. BLM field camp an site. Walls between the reserve and Pare pits have eroded. Wellhead and Water flows into surface gravel pad. ? No Wook #1 USGS I BLM Low lNone Name Yes water during break22L no data data Paye 10 of 14 0 0 SPAR Response with Legacy Wells Lrsl.xlsx BLM 2x13 Risk Well Name 10porator I RP I Land Mgr Priority CSP Status I File #IHazid Arca- Barrow Cure #1 US Na l til.M Avak 01 US Navy I BLM Barrow Bi R' #1 US Na I BLM Barrow Cafe Rig Test 91 US Na I BLM #2 I US Navy I BLM #1JUS N,a I BLM H' h NOr1e None Test Well #1 US Test Well #2 US Barrow Test Wetl #31115 Na IN©r1h Slo c Bora IAedium None None Unknown Page 11 of 14 Subsurface -FAOGCC Surface SPAR IWorkgfoup Notes Status _ ___ araiu5 Need HRR, PA, SI. Surface Cleanup, Photo CIMG0218 csg cemented at 53` shows area of disturbed tubing hung to 708': hole open casing vegetation that should be heft filled with drilling mud slicking up; wood & investi algid durin Sf and diesel metal debris open casing Need HRR. PA, St. Surface csg cemeoled at BIF. sticking up; wood & Cleanu-. lu set at 1348' metal debris Not abandoned, site not cleared, Need HRR, PA, SI. Surface open easing 7? No Cleanup no data data Not abandoned, site not eteared, Need HRR. PA, SI. 'Surface open casing 77 No Cteanu no data data Need HRR, PA, St with sampling. trilling mud assessment. Surface Cleanup. Drilling Muds on Not abandoned, site -slowly revegelatmg site not igred, More information on drilling open casing 7? No mud specifics rs being researched no data data Need 1lRR, PA, SI wdh sampling. Drilling mud wellhead leaking assessment. Surface cemented Csg to gas!? Wood & Cleanup- Cellar does not 1270;slotted liner to metal debris. Area retain water 1956': tbg to 1939 affected 50'x50' Need HRR, PA. SI. Drilling Csg cemented at mud assessment. Surface 441'.hole Iell willed with open pipe; metal & Cleanup- On mads stem water concmie debris Need HRR, PA, Sl. Drilling Csg cemented al 2260'; mud assessment- Surface periorated liner to TD. wood, metal & Cleariu . fln road s stem lin Completed well. Conerete debris Need HRR, PA, SI with sampling and workplan. Drilling mud assessment. Surface Cleanup. Drilling +csg cemented at 10461: open c5g slinking mud at surface. Sheen on hole left filled with drilling up; wood & metal surface wafer in well cell larQuids and wafer. de" 0 SPAR Response with Legacy Wells Lisl.xlsx Well Flame Operator I RP I Land Mgr BLM 201$ Risk Priority CSP Status File #ltiazid yr once oF— Historic Release? SPAR Workgroup Notes AOGCC Subsurface Salus g AOGCC Surface Status no data. Likely revegetaled. Removed from our list of wells of concern in < 50', no csg, no API#, October, 2012 Oumalik Foundation Tess A US Navy I BLM None-uncased hc None None lUnknown Need HRR, PA. not in AOGCC database Monlht Meeting no data. Likely revegetated. Removed from our fist of wells of concern in < 50', no csg, no API#, October, 2012 Cumalik Foundalion Test b US Navy I BLM None-uncased hC None jNane Unknown Need HRR. PA, not in AOGCC database Monthly Meeting no data. Likely revegetated. Removed From our irsl of wells of Concern In < 50', no csg. no API#, October, 2012 Oumalik Foundation Test A US Navy I BLM None-uncased hc None lNone Unknown Need HRR. PA, not m AOGCC database Monthly Meeting no data. Likely revegetated. Removed from our list of wells of concern in < 50', no c5g. no APF#. Odubut. 2012 Oumalik Foundation Test A US Navy I BLM None-uncased ht Nune lNone Unknown Need HRR, PA, nal in AOGCC database Monthiv Meetin no data. Likely revegetaled. Removed from our Ilst of wells of con cam in < 501, no csg, no APi#. October, 2012 Oumatik Foundation Test 0 US NavyI BLM None-uncased hc None None Unknown Need HRR. PA, not in AOGCC database Moral Meeting no data. Likely revegetaled. Removed from our list of wells of concern in < 50', no csg. no API#, October, 2012 Ournalik Foundation Test 4US Navy I BLM None4xwased h_j None None Unknown I Need HRR. PA, not in AOGCC database Month Meetin Page 12 of 14 0 Page 13 of 14 SPAR Response with Legacy Wells LrsLxisx Well Name BLM 2013 Risk Operator f RP I Land Mgr Priority Historic CSP Status Fife #IHazld Rslease7 AOGCC subsurface Status �__ - -_-�� . A013CC Surface Status no dala. Likely SPAR 1Norkgroup Nates revegelaled. Removed from our list of wells of concern in < 50'. no csg, no AP IN, October, 2012 Oumalik Foundation Test US Na!q BLM None -encased h None None Unknown Need HRR. PA. not w AOGCC database MonthlyMeetin no data. Likely revegelated. Removed from our list of wells of concern in < 501. no csg, no API#, October, 2012 Oumalik Foundalion rest U5 Na I BLM None -encased h None None Unknown Need HRR, PA, not in AOGCC database Monihl lAeeli no data. Likely revegetaled. Removed from aur fist of wells of concern in 0urn alik Foundation Test US Na 18 LM None -encased fi None None ilnknown Need HRR. PA, < 50', no csg. no API#, not in AOGCC database October, 2012 Month! Meetin no data. Likely revegetated. Removed from our list of wells of concern In < 50', no csg, no API#, October, 2012 Oumalik Foundat'Gon Test US Na I BLM None encased h Nome None Unknown Need HRR, PA, not m AOGCC database Month! Meeting property abandoned per then -applicable South Banow #7 US NEILM 2LI None None Unknown Need HRR. PA, ro erl lu ed re s no data to support proper Um -Qt 02 US N Noire Pendin Clo 335.30.001/3078 Yes, see file Plu d to surface abandonment no data to support proper Uncal #5 Ummt #9 Urrval A66 Umial #T Atiaaru Point#1 U5 US US Na I BL M US Na I BLM USGS/BLM None Pendin Hi h -PCB cleanu Active None Pendia None tPendi Mane Clo 3L5 313.00113079 335.38.00113093 Cao 335.3$.00113080 Clo 335 38 001I3091 None Yes, see file Yes, see file Yes, see file Yes. see lite No Plu ed E4 surface property plugged and abandoned pfupedy plugged and abandoned property plugged and abandoned Need HRR. PA,Plugged by properly plugged and BLM in 2009. abandoned abandonment suriaoe site rcmediated surface site remediated suriacx V le remediated surface site re medialed Page 13 of 14 SPAR Response with Legacy Wells LrsLxlsx Page 14 of 14 0 vrcTon`ce o BLM 2813 Risk Historic AOGCC Subsurface AOGCC Surface Well Name Operator i RP 1 Land Mgr Priority CSP Status File #fFlaxid Releases SPAR Workgroup Notes Status Status Add to Site list. Need HRR, PA. SI with workplan and sampling. Chilling mud assessment. Surface Cleanup. Two large breaches on the south side of the berm allow water out of the reserve pit. Plugged properly plugged and surface site Drew Point #1 USGS 1 BLM None None None Yes by BLM in 2410. abandoned remedialed On Site list Need HRR, PA, 51 with workplan and sampling. [frilling mud assessment. Surface Cleanup. In 1976 the reserve pit berm failed and dolling muds/cutlings were released onlo the Poe of Teshekpuk Lake. Plugged by BLM in 2008. Solid waste from camp aril drilling operations buried on northern portion of pad. Erosion has exposed solid properly plugged and surface site East Teshek uk #1 US Navy 1 BLM None Active - waits 3Q0.38.11012652 Ycs, see file waste. abandoned remediated Threatened by erosion. properly plugged and surface site J. W. Dalton $P USGS f BLM None None None No Plu ed b BLM in 20fl5. abandoned rernediated properly plugged and surface site South Barrow #8 USAF 1 BLM None None None Unknown Need HRR, PA, abandoned remediated properly plugged and surface sile South Bartow 911 US Na INorih Slope Bono None None None Unknown Need HRR, PA, abandoned remedialed properly plugged and surface site South Barrow 013 US Na lNerlh Slope Boro None None None Unknown Need HHR, PA, abandoned remedialed properly plugged and surface site South Barrow #15 US Na !North Sloe Boro None None None Unknown Need HRR, PA, abandoned remediated properly plugged and surface site South Barrow #19 US Na 1Nrarlh Sloe Baro None Nana None Unknown Need HRR. PA, abandoned remediated Properly plugged and surface site South Barrow 1x20 US Na Worth Slope Bora None None None Unknown Need HRR, PA, abandoned remedialed Need HRR, PA, dolling mud assessment, containment assessment, possible releases. Breaches allow wafer to flow into and aul of property plugged and surface site Watakpa #2 USGSI BLM None None lNone lyes I reserve and flare pits. labandoned irernediated Page 14 of 14 0 STATE OF ALASKA AL,.__A OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon U Repair Well U Plug Perforations U Perforate U Other U Run ESP . Performed: Alter Casing ❑ Pull Tubing❑✓ • Stimulate-Frac ❑ Waiver ❑ Time Extension E 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 0 Exploratory ❑ 100-148 • 3.Address: 3800 Centerpoint Drive,Suite 100 Stratigraphic❑ Service ❑ 6.API Number: Anchorage,Alaska 99504 50-133-10156-00 7.Property Designation(Lease Number): 8.Well Name and Number: FEDA028406 • Swanson River Unit(SRU)331-27. 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): N/A Swanson River Field/Hemlock Oil • 11.Present Well Condition Summary: RECEIVED Total Depth measured 12,046 feet Plugs measured 11,077 feet true vertical 12,046 feet Junk measured N/A feet DE.`' 0 2 2013 Effective Depth measured 11,077 feet Packer measured N/A feet AOGCC true vertical 11,077 feet true vertical N/A feet Casing Length Size MD TVD Burst Collapse Structural Conductor 22' 20" 22' 22' Surface 1,490' 13-3/8" 1,490' 1,490' 2,730 psi 853 psi Intermediate Production 11,620' 7" 11,620' 11,620' 604 psi 7,240 psi Liner Perforation depth Measured depth See Attached Schematic SCANNED APR 2 4 2014; True Vertical depth See Attached Schematic Tubing(size,grade,measured and true vertical depth) 3-1/2" 9.3#/L-80 10,701'MD 10,701'ND Packers and SSSV(type,measured and true vertical depth) N/A N/A, N/A N/A 12.Stimulation or cement squeeze summary: N/A Intervals treated(measured): N/A Treatment descriptions including volumes used and final pressure: N/A 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 154 171 378 1150 200 Subsequent to operation: 220 89 626 150 150 14.Attachments: 15.Well Class after work: Copies of Logs and Surveys Run N/A Exploratory❑ Development❑✓ ' Service ❑ Stratigraphic ❑ Daily Report of Well Operations X 16.Well Status after work: Oil p. Gas ❑ WDSPL❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP❑ SPLUG❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: 313-578 Contact Stan Porhola Email sporhola(C hilcorp.com Printed Name Stan Porhola Title Operations Engineer Signature ��' c/ii.11 .._ Phone 907-777-8412 Date k 27 c(.z 3.pi RSD S DEC 13 2iD'_, Form 10 404 Revised 10/2012 4 - v/6,4 Submit Original Only f � Hilcorp Alaska, LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date SRU 331-27 50-133-10156-00 100-148 11/13/13 11/19/13 Daily Operations: 11/13/2013 -Wednesday Laid containment and seals. Removed flow and gaslift lines from well. MIRU WOR and Associated equipment. Installed winterization kit over rig and equipment. 11/14/2013 -Thursday Finished RU/Winterization and prep to test BOPE. Witness tested BOPE by Lou Grimaldi per AOGCC Approval,Valves 250- 3,000psi, Rams 250-3,000psi, Annular 250-1,500psi, Koomey Unit and Gas Detection. No failures were recorded. Opened the csg to the rig tank. MU 3-1/2" 8rd lifting jnt and backed out the hanger lockdown pins. PU to 108k and pulled tbg hgr above floor. Set slips and L/D tbg hgr. RU SLB to reel power cable and control line up. TOOH w/45 stands of 3-1/2" 8rd at report time. 11/15/2013 - Friday SOOH with total 167 stands 3-1/2" 8rd tbg, esp cable and control lines. Starting from stand 105 to 167 we lost 57 3/4" SS bands in the hole. Flushed the control lines with antifreeze and L/D the ESP sections. No visible wear on the ESP equipment. Realeased SLB. MIRU SL, PU 5.8" Junk Basket and TIH to 4,000' and set down. POOH w/4 band. RIH w/same and seat down 6,595'. POOH w/0 bands. RIH w/5"4 prong grab to 8,000'. POOH w/20 bands. RIH w/same 11,100'-tag and POOH w/ 15 bands. RIH w/same to 11,100', POOH 14 bands at report time. 11/16/2013 -Saturday TIH w/5" 4 prong grab to 11,100', POOH w/1 band. PU and RIH 4.5 cent 3.7" magnet to 11.100', POOH w/no bands. PU and RIH w/4 prong wire garb to 11,100', POOH w/no bands. PU and RIH w/3.7" LIB and tagged bottom at 11,100', POOH w/ impression of junk. PU and RIH w/5.8" GR and tagged bottom at 11,100' wlm, POOH. RDMO SL. Made ESP splice for the Leader. Made up the ESP motor section and intake. 11/17/2013 -Sunday MU the 4 pump sections. TIH w/ESP, control lines, GLM and with 78 stands of3-1/2" 8rd tbg, Banding ESPcable times per joint and the control line 1 band every other joint. Made the 1st cable splice at 5,912'. TIH w/ESP, control lines, GLM and 40 stands of 3-1/2" 8rd tbg at report time. 11/18/2013 - Monday Continued TIH w/ESP, and 330 jts of 3-1/2" 8rd tbg, ESP cable and control lines. PU a 1,000' spool of power cable. Made the splice (159'). Continued TIH w/4 jts of 3-1/2" 8rd tbg, power cable and control line. MU the tbg hanger and measure the esp cable. Made the cut and spliced the pigtail on. Ran the penetrator and control lines thru the hanger. Landed the hanger with 105k down. Secured the lockdown pins. Set the BPV and ND the BOP's. NU the production tree at report time. 334 jts of 3-1/2" EUE L-80 8rd 10,636' GLM #1 10,600', GLM #2 7,974', GLM #3 5,853'. Pump intake is at 10,788'. Bottom of ESP at 10819.9'. Total SS Bands 1184, 3 bands per jt for the ESP cable and 1 band ever other jt for the control line. 11/19/2013 -Tuesday NU the production tree. Pulled the BPV. Tied-in the flowlines and ESP cable. Begin the ESP start up procedure. RDMO the Moncla 405. Well started making fluid at 4pm. Swanson River Unit Well: SRU 331-27 .. ACTUAL SCHEMATIC Completion Ran: 11/19/2013 Hilcorp Alaska,LLC PTD: 100-148 API: 50-133-10156-00 RKB:272'/GI:257'AMSL KB-THF:15.0' Casing Detail Size Type Wt Grade ID Top Btm Hole Cmt Cmt Top \-_./20" j : 1 ''L, 20" Conductor . - - - Surf 22' - unknown Surf. 5 " 22 13-%" Surface 54.5 J-55 12.615" Surf 1,490' 18 /8 1,500 sx Surf. 1,497' • r7" 29 P-110 6.184" Surf 1,027' 12 2,725' 13-3/8". 7" 29 N-80 6.184" 1,027' 2,172' 10-Ys" 1,490' Prod Csg 11,659' 1,000 sx 9,140'CBL 7" 26 N-80 6.276" 2,172' 8,192' 7" 29 N-80 6.184" 8,192' 10,695' 7" 29 P-110 6.184" 10,695' 11,620' Tubing Detail Cplg OD ( 2 3.5" EUE 8RD 9.3 L-80 2.992" Surface 10,701' 4.500" Jewelry Detail No. Depth ID OD Item 1 17' 2.992" 6.184" Tubing Hanger w/8RD Box Down(8RD Pin Up on Full Jt Below) 2 5,853' 2.992" 5.313" Gaslift Mandrel,Camco MM,Dummy Valve 3 7,974' 2.992" 5.313" Gaslift Mandrel,Camco MM,Dummy Valve CBL TOC 4 10,600' 2.992" 5.313" Gaslift Mandrel,Camco MM,Dummy Valve 9,140' 5 10,701' - 4.000" Top of ESP,Discharge Head ,; " 6 10,788' - 4.000" ESP Intake I It7 4 7 10,788' 4.950" 5.500" ESP Shroud(31'of 5-1/2"15.5#Casing) ' 8 10,820' - 5.520" Base of ESP,456 series Motor/400 series Pumps S 9 11,077' - - Lost 7 ea%"SS bands(5.8"GR tagged on bottom 11/16/13) 5 10 11,077' - - Cement Retainer,Capped w/10 sx cement 000001 tr' -� 6 . Cable/Clamp/Band Detail ;;. ' ' 10,800'-10,820' - 8 ea 4560 Cannon Clamps(Across Motor Only) 111 ,y , , 10,701'-10,800' - 18 ea 4010 Cannon Clamps(Across Pumps/Poseidon Gas Handler/Protector) 8 10,671'-10,701' - 9 ea%"SS bands(all on l'`joint above discharge head) 1.! 0'-10,671' - 3 ea%"SS bands per tubing joint(additional 1 ea for flatpack every other joint) - wS0 (Total of 1184 SS bands) 0 C 0'-10,680' - 1 ea Reda#1 Round ESP Cable(Splices at approx.35', 159', 5,912',and 10,680') H-4 10,680'-10,800' - 1 ea MLE Flat Cable(Splice depth at approx.. 10,680') - 0'-10,702' - 1 ea Dual Flatpack Encapsulated Control Lines(2 ea Chem Inj) L- 10,702'-10,820' - 1 ea Tri Flatpack Encapsulated Control Lines(2 ea Chem In), 1 ea Phoenix) - H-5 Perforation History 0, - wso Date Zone Top(MD) Btm(MD) Top(MD) Btm(MD) Amt spf Comments ' ' ' H-6 12/11/58 WSO 10,795' 10,796' 10,795' 10,796' 1' 4 Y 12/14/58 H-4 10,804' 10,836' 10,804' 10,836' 32' 4 Squeezed Milled K H 7 12/14/58 H-5 10,849' 10,878' 10,849' 10,878' 29' 4 Squeezed retainer 12/11/58 WSO 10,880' 10,881' 10,880' 10,881' 1' 4 to . H-10 11,077' i9 `; - Hemlock 8/31/2012 H-6 10,906' 10,916' 10,906' 10,916' 10' 6 2.5"Owen 10 8/31/2012 H-7 10,926' 10,948' 10,926' 10,948' 22' 6 2.5"Owen 12/09/58 Hemlock 11,038' 11,060' 11,038' 11,060' 22' 4 Open - - 7,. _ _Hemlock 8/31/2012 H-10 11,050' 11,076' 11,050' 11,076' 26' 6 2.5"Owen 11,620' : r • "' _ 12/07/58 Hemlock 11,185' 11,195' 11,185' 11,195' 10' 4 Isolated TD=12,046' PBTD=11,077' Downhole Revised: 11/19/13 Revised By STP 11/23/13 k • THE STATE Alaska Oil and Gas - f o s v don Commission GOVERNOR SEAN PARNELL 333 West Seventh Avenue Anchorage, Alaska 99501-3572 ALAS Main: 907.279.1 433 i s y: Fax: 907.276.7542 Stan Porhola satO � I Operations Engineer ao Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 100 Anchorage, AK 99503 Re: Swanson River Field, Hemlock Oil Pool, SRU 331-27 Sundry Number: 313-578 Dear Mr. Porhola: 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, Cathy P. 'oerster Chair, Commissioner DATED this t day of November, 2013. Encl. • , im,, ,Dze-lki'l; i 1 ',"' ,.:-': 70 STATE OF ALASKA \\� NOV t t 2U.; ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 1.Type of Request: Abandon❑ Plug for Redril ❑ Perforate New Pod❑ Repair WOO Change Approved Program❑ Suspend❑ Plug Perforations❑ Perforate❑ Pull Tubing El ° Timg Extension❑ s-• Operations Shutdown❑ Re-enter Susp.Wel ❑ Stimulate❑ Alter Casing[1] Oth Run ESP El- 1 2.Operator Name: rg Hilcorp Alaska,LLC 4.Current Well Class: 5.Permit to D Number. Exploratory ❑ Development la • 100-148 3.Address: 3800 Centerpoint Drive,Suite 100 Stratigraphic ❑ Service ❑ 6.API Number. - Anchorage,Alaska 99503 50-133-10156-00 7.If perforating: 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? CO 123B Swanson River Unit(SRU)331-27. Will planned perforations require a spacing exception? Yes ❑ No El 9.Property Designation(Lease Number): 10.Field/Pool(s): FEDA028406 Swanson River Field/Hemlock Oil - 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth ND(ft): Effective Depth MD(ft): Effective Depth ND(ft): Plugs(measured): Junk(measured): 12,046 12,046 11,077 11,077 11,07T N/A Casing Length Size MD Tt/D Burst Collapse Structural Conductor 22' 20" 22' 22' Surface 1,490' 13-3/8" 1,490' 1,490' 2,730 psi 853 psi Intermediate Production 11,620' 7" 11,620' 11,620' 605 psi 7,240 psi Liner Perforation Depth MD(ft): Perforation Depth ND(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See Attached Schematic See Attached Schematic 3-1/2" 9.3if/L-80 10,565' Packers and SSSV Type: Packers and SSSV MD(t)and ND(It): N/A;N/A WA:N/A 12.Attachments: Description Summary of Proposal 0 13.Well Class after proposed work: Detailed Operations Program n BOP Sketch (] Exploratory n Stratigraphicn Development n .Service n 14.Estimated Date for 15.Well Status after proposed work: Commencing Operations: 11/09/13 Oil El - Gas ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: WINJ ❑ GINJ ❑ WAG ❑ Abandoned 0 Commission Representative: GSTOR ❑ SPLUG El 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Stan Porhola Phone: 907-777-8412 Email sDorhola a( hilcorD.corn Printed Name Stan Porhola Title Operations Engineer Signature 27(g-Z' Phone 907-777-8412 Date R/I (! t 3 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 3\3— S7g Plug Integrity ❑ BOP Test Mechanical Integrity Test ❑ Location Clearance ❑ Other: # ?n„0 SG 1501 iS r RBENIS NOV 21 4 Spacing Exception Required? Yes ❑ No d Subsequent Form Required: /O—41 07 / , --- APPROVED BY / ' , Approved by: (9-7.67 _-),{-,�, COMMISSIONER THE COMMISSION Date: l[ (� f'� RilaG JA�,3 Submit Form and Form 10-403(Revised 10/2012) Appr a i om the date of approval. ! Attachments in Duplicate ` AC C Well Prognosis Well: SRU 331-27 Hilcorp Alaska,LL Date:11/04/2013 Well Name: SRU 331-27 API Number: 50-133-10156-00 Current Status: ESP Oil Well Leg: N/A Estimated Start Date: November 9th, 2013 Rig: Moncla#405 Reg.Approval Req'd? 403 Date Reg.Approval Rec'vd: Regulatory Contact: Donna Ambruz 777-8305 Permit to Drill Number: 100-148 First Call Engineer: Stan Porhola (907)777-8412 (0) (907)331-8228(M) Second Call Engineer: Chad Helgeson (907)777-8405 (0) (907)229-4824(M) AFE Number: Current Bottom Hole Pressure: —3,117 psi @ 10,841' ND (Static survey April 2012 mid perf of 10,841' MD) Maximum Expected BHP: —3,117 psi @ 10,841' TVD (Static survey April 2012 mid perf of 10,841' MD) Max.Allowable Surface Pressure: —0 psi (Based on actual reservoir conditions and min water cut of 50% (0.385psi/ft) will balance reservoir pressure at 2,745 ft. TVD. Brief Well Summary This well was drilled and completed as an oil well in Hemlock benches H-4, H-5,& H-10 in 1958.A workover performed in 1963 isolated the H-10 and reperforate the H-4& H-5 zones.A workover in 1971 converted the well to gas injection. Gas injection was halted in 1981 and the well remained shut in until 2012.A workover performed in 2012 was performed to pull tubing and packers,cement squeeze the H-4 and H-5, pressure test casing,drill out cement, pressure test squeeze,cleanout fill, BPs, perforate H-6, H-7,and H-10 and ran a GL completion.The gaslift completion was pulled and converted to ESP completion in mid-July 2013. Upon initial startup of the ESP,a downhole failure occurred.The ESP was pulled and found to have a downhole pump failure (yet to be determined).The gaslift completion was re-ran to put the well back on production until a new ESP pump can be delivered.A capillary string was installed in early August 2013 to help with existing emulsion issues.The capillary string and gaslift completion were pulled and an ESP installed in September 2013. Plan is / to pull the failed ESP and run a new ESP. Notes Regarding Wellbore Condition • ESP is currently down (likely failed pumps due to downthrust). Work-Over Rig Procedure 1. MIRU Moncla#405 pulling unit. 2. RU and pump+/-50 bbl Produced Water down tubing to clean pipe. Bleed casing pressure. 3. Set TWC in tubing hanger, ND tree, NU 7-1/16" BOPE and test to 250psi low/3,000psi high, annular to 250psi low/1,500psi high (hold each valve and test for 5-min). Record accumulator pre-charge pressures. a. Notify AOGCC 24hrs in advance to witness test. b. Crew will be working 12hr shifts and well will be secured nightly with TIW valves and BOPE. 4. Release test pressure, pull TWC and install handling sub in hanger. 5. Back out tbg hanger hold down pins and pick up on hanger. 6. SOOH w/all tubing and lay down failed ESP pump. Well Prognosis Well: SRU 331-27 Hilcosy Alaska,LL Date:11/04/2013 a. Keep 3 GLM to re-run with ESP completion. 7. RIH with new ESP with existing 3-1/2" 8rd EUE L-80 tubing. a. Test control lines to 2,500 psi. b. RU Pollard to use SS bands on tubing(ensure adequate banding material). c. Set 3 re-run GLMs at+/- 10,600',+/-8,000',and+/-6,000'. d. Run ESP cable around Minor OD of the GLMs(will not fit across Major OD). e. Have 3-6 joints of 3-1/2" EUE 8RD to reach a planned set depth of+/-10,862'. 8. Set base of ESP at+/-10,862' (Pump intake around+/- 10,775'). Land tubing hanger. 9. Set BPV, ND BOPs, NU Tree,test tree to 3,000 psi. a. Note: Rated pressure of BIW penetrator(wellhead to cable connection) is 3,000 psi. 10. RDMO workover rig and equipment. 11. Turn well over to production. Attachments: 1. As-built Schematic 2. Proposed Schematic 3. BOP Schematic • Swanson River Unit H . Well: SRU 331-27 ACTUAL SCHEMATIC Completion Ran: 9/27/2013 llilcarp Alaska,LLC PTD: 100-148 API: 50-133-10156-00 RKB:272'/GL:257'AMSL Casing Detail KB-THF:15.0' 20" Size Type Wt Grade ID Top Btm Hole Cmt Cmt Top 4 1 r;i 20" Conductor Surf 22' unknown Surf. 18-%" 22 13-3/8" Surface 54.5 J 55 12.615" Surf 1,490' 1,497' 1,500 sx Surf. 7" 29 P-110 6.184" Surf 1,027' 2,725 13-3/8"4 el'' 7" 29 N-80 6.184" 1,027' 2,172' 10-%s" 1,490' Prod Csg 11,659' 1,000 sx 9,140'CBL 7" 26 N-80 6.276" 2,172' 8,192' 7" 29 N-80 6.184" 8,192' 10,695' 7" 29 P-110 6.184" 10,695' 11,620' Tubing Detail Cplg OD 2 i' 3.5" EUE 8RD 9.3 L-80 2.992" Surface 10,565' E.ii ' -' a r 4.500" Jewelry Detail I No. Depth ID OD Item 1 17' 2.992" 6.184" Tubing Hanger w/8RD Box Down(8RD Pin Up on Full Jt Below) 3 2 5,935' 2.992" 5.313" Gaslift Mandrel,Camco MM,Dummy Valve 3 7,927' 2.992" 5.313" Gaslift Mandrel,Camco MM,Dummy Valve CBL TOC 4 9,980' 2.992" 5.313" Gaslift Mandrel,Camco MM,Dummy Valve 9,140' �' 5 10,565' - 4.000" Top of ESP,Discharge Head ;1 6 10,769' 5.520" Base of ESP,456 series Motors/400 series Pumps 4 MR ' r 7 11,077' - - Cement Retainer,Capped w/10 sx cement 4 Cable/Clamp/Band Detail 5 10,702'-10,769' - 8 ea 4560 Cannon Clamps(Across Motors Only) kA41 1044" ;j 10,564'-10,702' - 18 ea 4010 Cannon Clamps(Across Pumps/Gas Handler) ir 01 41 10,534'-10,564' - 9 ea%"SS bands(all on 1st joint above discharge head) 44 0'-10,534' - 3 ea%"SS bands per tubing joint(additional 1 ea for flatpack every other joint) 0'-10,582' - 1 ea Reda#1 Round ESP Cable(Splice depths at approx.35',4,082',and 10,582') 6 10,582'-10,734' - 1 ea MLE Flat Cable(Splice depth at approx..10,582') WSO 0'-10,545' - 1 ea Dual Flatpack Encapsulated Control Lines(2 ea Chem Inj) 10,545'-10,769' - 1 ea Tri Flatpack Encapsulated Control Lines(2 ea Chem Inj,1 ea Phoenix) H-4 'tea Perforation History k' H_5 Date Zone Top(MD) Btm(MD) Top(MD) Btm(MD) Amt spf Comments L 12/11/58 WSO 10,795' 10,796' 10,795' 10,796' 1' 4 WSO 12/14/58 H-4 10,804' 10,836' 10,804' 10,836' 32' 4 Squeezed .,w H-6 12/14/58 H-5 10,849' 10,878' 10,849' 10,878' 29' 4 Squeezed 12/11/58 WSO 10,880' 10,881' 10,880' 10,881' 1' 4 Milled K a H-7 8/31/2012 H 6 10,906' 10,916' 10,906' 10,916' 10' 6 2.5"Owen retainer .'' r to 1 H-10 8/31/2012 H-7 10,926' 10,948' 10,926' 10,948' 22' 6 2.5"Owen 11,077' coV Hemlock 12/09/58 Hemlock 11,038' 11,060' 11,038' 11,060' 22' 4 Open 7 ' 4" *. 8/31/2012 H-10 11,050' 11,076' 11,050' 11,076' 26' 6 2.5"Owen irk' ItPt 12/07/58 Hemlock 11,185' 11,195' 11,185' 11,195' 10' 4 Isolated 7„ _ _Hemlock 11,620'‘jitzteiniri TD=12,046' PBTD=11,077' Downhole Revised:9/27/13 Revised By STP 11/04/13 • Swanson River Unit Well: SRU roposed 331 Com 27 PROPOSED SCHEMATIC Ppletion Hilcorp Alaska,LLC PTD: 100-148 API: 50-133-10156-00 RKB:272'/GL:257'AMSL Casing Detail KB-THF:15.0' Size Type Wt Grade ID Top Btm Hole Cmt Cmt Top 's--..2 1 .. g'' 20" Conductor - - - Surf 22' - unknown Surf. 20" 22' 18%" 13-%" Surface 54.5 J-55 12.615" Surf 1,490' 1,500 sx Surf. 1,497' ', 12-%" 7" 29 P-110 6.184" Surf 1,027' 2,725' 13-3/8" - 7" 29 N-80 6.184" 1,027' 2,172' 10-% 1,490' Prod Csg 11,659' 1,000 sx 9,140'CBL 7" 26 N-80 6.276" 2,172' 8,192' 7" 29 N-80 6.184" 8,192' 10,695' 7" 29 P-110 6.184" 10,695' 11,620' Tubing Detail Cplg OD I N 2 3.5" EUE 8RD 9.3 L-80 2.992" Surface 10,657' 4.500" Jewelry Detail No. Depth ID OD Item 1 17' 2.992" 6.184" Tubing Hanger w/8RD Box Down(8RD Pin Up on Full Jt Below) I h1 3 2 6,000' 2.992" 5.313" Gaslift Mandrel,Camco MM,Dummy Valve 3 8,000' 2.992" 5.313" Gaslift Mandrel,Camco MM,Dummy Valve CBLTOC 4 10,600' 2.992" 5.313" Gaslift Mandrel,Camco MM,Dummy Valve 9,140' 5 10,657' - 4.000" Top of ESP,Discharge Head F 6 10,775' - 4.000" ESP Intake INIIIIIII 1 7 10,862' - 5.520" Base of ESP,456 series Motors/400 series Pumps 8 11,077' - - Cement Retainer,Capped w/10 sx cement 5 Cable/Clamp/Band Detail 10,795'-10,862' - 8 ea 4560 Cannon Clamps(Across Motors Only) 10,657'-10,795' - 18 ea 4010 Cannon Clamps(Across Pumps/Gas Handler) _� 6 10,627'-10,657' - 9 ea 3"SS bands(all on 152 joint above discharge head) w.;, 0'-10,627' - 3 ea%"SS bands per tubing joint(additional 1 ea for flatpack every other joint) t'-' 7 0'-10,675' - 1 ea Reda#1 Round ESP Cable(Splice depths at approx.35',4,675',and 10,675') wSO 10,675'-10,827' - 1 ea MLE Flat Cable(Splice depth at approx.. 10,675') 0'-10,638' - 1 ea Dual Flatpack Encapsulated Control Lines(2 ea Chem Inj) H-4 10,638'-10,862' - 1 ea Tri Flatpack Encapsulated Control Lines(2 ea Chem In), 1 ea Phoenix) Perforation History =- H-5 Date Zone Top(MD) Btm(MD) Top(MD) Btm(MD) Amt spf Comments - 12/11/58 WSO 10,795' 10,796' 10,795' 10,796' 1' 4 - WSO 12/14/58 H-4 10,804' 10,836' 10,804' 10,836' 32' 4 Squeezed ` H-6 12/14/58 H-5 10,849' 10,878' 10,849' 10,878' 29' 4 Squeezed 12/11/58 WSO 10,880' 10,881' 10,880' 10,881' 1' 4 Milled K H-7 8/31/2012 H-6 10,906' 10,916' 10,906' 10,916' 10' 6 2.5"Owen retainer ' to H-10 8/31/2012 H-7 10,926' 10,948' 10,926' 10,948' 22' 6 2.5"Owen 11,077' Hemlock 12/09/58 Hemlock 11,038' 11,060' 11,038' 11,060' 22' 4 Open 8 8/31/2012 H-10 11,050' 11,076' 11,050' 11,076' 26' 6 2.5"Owen _ _ 12/07/58 Hemlock 11,185' 11,195' 11,185' 11,195' 10' 4 Isolated _ Hemlock 11,620' _ TD=12,046' PBTD=11,077' Downhole Proposed Revised By STP 11/04/13 , ll • i Swanson River 2013 Moncla Rig 405 Knight Oil Tools BOP IGharp:%luau-IAA f 1 0 • , III ill iii I iii if ii III 2.57' / Shaffer 7 1/16 5000 Illinifthinia / 2 3/8-3'/variable Al■ CAMERON 3.68 _� �' '�■ _ • ���_ Blind ' 71/16 5000 I-���= ■ I' ® ~Imam " �N Iii 111"111 111 111 ' — Choke and Kill valves are 2 1/1610M - / 1 - Ill III I#.1 Ill lit - , 1.56' oIw1i, •` 1/16 5000 ,; r� i , „a i�� i 7 0 A 111 111:,:111 111 III '�'�, , RECEIVED STATE OF ALASKA ALA.OIL AND GAS CONSERVATION COMMI ON OCT 14 2013 REPORT OF SUNDRY WELL OPERATIONS AOGCC 1.Operations Abandon ❑ Repair Well ❑ Plug Perforations ❑ Perforate ❑ Other U Run ESP Performed: Alter Casing ❑ Pull Tubing 0 Stimulate-Frac D 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 ❑ 100-148 i 3.Address: 3800 Centerpoint Drive,Suite 100 Stratigraphic❑ Service ❑ 6.API Number: Anchorage,Alaska 99504 50-133-10156-00 7.Property Designation(Lease Number): 8.Well Name and Number: FEDA028406 ' Swanson River Unit(SRU)331-27 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): N/A Swanson River Field/Hemlock Oil • 11.Present Well Condition Summary: Total Depth measured 12,046 feet Plugs measured 11,077 feet true vertical 12,046 feet Junk measured N/A feet Effective Depth measured 11,077 feet Packer measured N/A feet true vertical 11,077 feet true vertical N/A feet Casing Length Size MD ND Burst Collapse Structural Conductor 22' 20" 22' 22' Surface 1,490' 13-3/8" 1,490' 1,490' 2,730 psi 853 psi Intermediate Production 11,620' 7" 11,620' 11,620' 604 psi 7,240 psi Liner Perforation depth Measured depth See Attached Schematic True Vertical depth See Attached Schematic sumo NuV 2013 Tubing(size,grade,measured and true vertical depth) 3-1/2" 9.3#/L-80 10,565'MD 10,565'ND Packers and SSSV(type,measured and true vertical depth) N/A N/A N/A N/A 12.Stimulation or cement squeeze summary: N/A Intervals treated(measured): N/A Treatment descriptions including volumes used and final pressure: N/A 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 128 122 344 1100 185 Subsequent to operation: 337 20 507 150 150 14.Attachments: 15.Well Class after work: Copies of Logs and Surveys Run N/A Exploratory❑ Development 0 - Service ❑ Stratigraphic ❑ Daily Report of Well Operations X 16.Well Status after work: Oil El. Gas ❑ WDSPL❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP❑ SPLUG❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: 313-466 Contact Stan Porhola Email sp0rh018t�hiI )1p.__om Printed Name Stan Porhola Title Operations Engineer Signature 4�'-'" 666 y,., -� Phone 907-777-8412 Date (0/;( ) 3 tS P '� 0 RBDMS OCT 443'2013 Form 10-404 Revised 10/2012 4*W , r:r 4 Submit Original Only • • Soldotna Creek Unit Well: SRU 331-27 ACTUAL SCHEMATIC Completion Ran: 9/27/2013 Hilcorp Alaska,LLC PTD: 100-148 API: 50-133-10156-00 RKB:272'/GL:257'AMSL KB-THF:15.0' Casing Detail Size Type Wt Grade ID Top Btm Hole Cmt Cmt Top " 1 20" Conductor - - - Surf 22' - unknown Surf. 20" V3 22' r'.. 18-%" 13-%" Surface 54.5 J-55 12.615" Surf 1,490' 1,497' 1,500 sx Surf. "' ' 12 %„ 7" 29 P-110 6.184" Surf 1,027' 2,725 ill 13-3/8".7a Le 7" 29 N-80 6.184" 1,027' 2,172' 10-%" 1,490' Prod Csg 11,659' 1,000 sx 9,140'CBL 7" 26 N-80 6.276" 2,172' 8,192' 7" 29 N-80 6.184" 8,192' 10,695' 7" 29 P-110 6.184" 10,695' 11,620' Tubing Detail Cplg OD 3.5" EUE 8RD 9.3 L-80 2.992" Surface 10,565' �,. 4.500" 2 l' Jewelry Detail No. Depth ID OD Item 1 17' 2.992" 6.184" Tubing Hanger w/8RD Box Down(8RD Pin Up on Full Jt Below) 3 2 5,935' 2.992" 5.313" Gaslift Mandrel,Camco MM,Dummy Valve 3 7,927' 2.992" 5.313" Gaslift Mandrel,Camco MM,Dummy Valve CBLTOC 4 9,980' 2.992" 5.313" Gaslift Mandrel,Camco MM,Dummy Valve 9'140 „_ v °$, 5 10,565' 4.000" Top of ESP,Discharge Head 6 10,769' 5.520" Base of ESP,456 series Motors/400 series Pumps 4 ' 7 11,077 - Cement Retainer,Capped w/10 sx cement ie ....4 a: 5 Cable/Clamp/Band Detail 10,702'-10,769' - 8 ea 4560 Cannon Clamps(Across Motors Only) 10,564'-10,702' - 18 ea 4010 Cannon Clamps(Across Pumps/Gas Handler) b 10,534'-10,564' - 9 ea%"SS bands(all on 1st joint above discharge head) 0'-10,534' - 3 ea%"SS bands per tubing joint(additional 1 ea for flatpack every other joint) `' 6 0'-10,582' - 1 ea Reda#1 Round ESP Cable(Splice depths at approx.35',4,082',and 10,582') 10,582'-10,734' - 1 ea MLE Flat Cable(Splice depth at approx..10,582') w50 0'-10,545' - 1 ea Dual Flatpack Encapsulated Control Lines(2 ea Chem lnj) i,. 10,545'-10,769' - 1 ea Tri Flatpack Encapsulated Control Lines(2 ea Chem Inj,1 ea Phoenix) , H-4 Perforation History 5 H-s Date Zone Top(MD) Btm(MD) Top(MD) Btm(MD) Amt spf Comments i 12/11/58 WSO 10,795' 10,796' 10,795' 10,796' 1' 4 :at WSO 12/14/58 H-4 10,804' 10,836' 10,804' 10,836' 32' 4 Squeezed H-6 12/14/58 H-5 10,849' 10,878' 10,849' 10,878' 29' 4 Squeezed 12/11/58 WSO 10,880' 10,881' 10,880' 10,881' 1' 4 Milled K H 7 8/31/2012 H-6 10,906' 10,916' 10,906' 10,916' 10' 6 2.5"Owen retainer '4, to 4', H-i0 8/31/2012 H-7 10,926' 10,948' 10,926' 10,948' 22' 6 2.5"Owen 11,077' i Hemlock 12/09/58 Hemlock 11,038' 11,060' 11,038' 11,060' 22' 4 Open 7 ;i-' '- ' v. - ,*` 8/31/2012 H-10 11,050' 11,076' 11,050' 11,076' 26' 6 2.5"Owen 12/07/58 Hemlock 11,185' 11,195' 11,185' 11,195' 10' 4 Isolated Hemlock 11,620'i , , q TD=12,046' PBTD=11,077' Downhole Revised:9/27/13 Revised By STP 10/07/13 • • Hilcorp Alaska, LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date SRU 331-27 50-133-10156-00 100-148 9/19/13 9/28/13 Daily Operations: 09/19/2013-Thursday Rig Up Cap String Truck. Rig up lubricator and adapter. Test to 3,000 psi. Pull 3/8" capillary string from 10,800'. RDMO Cap String Truck. 09/23/2013- Monday Laid containment, spotted WO equipment and sealed. RD Flowline and GL lines. Set BPV, ND tree and NU 7-1/16" BOP stack. RU kill/choke manifold. Connected Koomey lines to BOP stack. Performed shell test on manifold. Waited on electrician to hard wire Koomey unit to generator. 09/24/2013 -Tuesday BOP Tested -250 psi low/3,000 psi high (witness waived by Lou Grimaldi,AOGCC). Pull and lay down tubing hanger. Work and unseat packer. SOOH 31 stands. Secure well. SDFN. 09/25/2013 -Wednesday Replaced 3 GLV with dummies to run with ESP completion. PU ESP BHA. 2' x 4.56" centralizer, 1.90' x 4.50" base gauge, 31.30' x 4.56" motor, 31.60' x 4.56" motor, 8' x 4" protector, 8' x 4" protector, 3.30'x 4" intake, 6.60' x 4" AGH, 22' x 4" pump, 22' x 4" pump, 22' x 4" pump, 22' x 4" pump, .75" x 4.63" discharge pressure sub assy and .80' x 4" head. Note: Motor did not test, replaced motor and tested ok at report time. 09/26/2013-Thursday TIH w/ESP and 90 stands of 3-1/2" 9.3 EUE 8rd tbg and 3 GLM with dummies. Set GLV at 6,000',8,000' and 10,000'. Note: 3 bands per joint on power cable and 1 band every other joint. Swapped cable spools and made splice. Continued in the hole with ESP. 130 stands in the hole at report time. 09/27/2013 - Friday Continue RIH w/37 stands, ESP, power cable and control lines. EOP: 10,768.99'; GLV#1: 9,979.83'; GLV#2: 7,926.60'; GLV#3: 5,935.08'. Made Surface splice for ESP power cable connection. Made up tbg hanger, ran dual-pack.25" control line and power cable thru hanger. Landed hanger and tested. Installed BPV, ND BOP stack. Tested the control lines an NU production tree. Pulled BPV and Installed flowline. 09/28/2013-Saturday RDMO WOR/Equipment and containment. e • • ,§)-„ 1,7,,-,s,, THE STATE Alaska Oil and Gas 1 l l 1sKA Conservation Commission GOVERNOR SEAN PARNELL , 333 West Seventh Avenue pF Anchorage, Alaska 99501-3572 ALASY' Main: 907.279.1433 Fax: 907.276.7542 SCANNED NOV ?_01 . Stan Porhola Operations Engineer b f t Hilcorp Alaska, LLC / 0 3800 Centerpoint Drive, Suite 100 Anchorage, AK 99503 Re: Swanson River Field, Hemlock Oil Pool, SRU 331-27 Sundry Number: 313-466 Dear Mr. Porhola: 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, Daniel T. Seamount, Jr. ..�.� Commissioner DATED this I/ day f September,2013. Encl. • 114,0,it LECEWED STATE OF ALASKA ll/lt AUG 2 7 2013 ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS AOGGC 20 AAC 25.280 1.Type of Request: Abandon❑ Plug for Redril ❑ Perforate New Pod❑ Repair WeII❑ Change Approved Program❑ Suspend❑ Plug Perforations❑ Perforate❑ Pull Tubing ill . Time Extension❑ Operations Shutdowi❑ Re-enter Susp.Wel ❑ Stimulate❑ Alter Casing❑ I Oth @T. ESP 51er 1151 - 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number. ,/I //r� Hilcorp Alaska,LLC 100-148 D' Exploratory ❑ Development 0 3.Address: 3800 Centerpoint Drive,Suite 100 Stratigraphic ❑ Service ❑ 6.API Number. Anchorage,Alaska 99503 50-133-10156-00 7.If perforating: 8.Well Name and Number What Regulation or Conservation Order governs well spacing in this pool? CO 123A Swanson River Unit(SRU)331-27 • Will planned perforations require a spacing exception? Yes ❑ No El 9.Property Designation(Lease Number): 10.Field/Pool(s): FEDA028406 • Swanson River Field/Hemlock Oil ' 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth ND(ft): Effective Depth MD(ft): Effective Depth ND(ft): Plugs(measured): Junk(measured): 12,046 ' 12,046 • 11,077 11,077 11,077' N/A Casing Length Size MD NVD Burst Collapse Structural Conductor 22' 20" 22' 22 Surface 1,490' 13-3/8" 1,490' 1,49(7 2,730 psi 853 psi Intermediate Production 11,620' 7" 11,620' 11,620' 605 psi 7,240 psi Liner Perforation Depth MD(ft): Perforation Depth ND(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See Attached Schematic See Attached Schematic 3-1/2" 9.3#/L-80 10,816' Packers and SSSV Type: Packers and SSSV MD(t)and ND(ft): Arrowset AS1-X Mech;N/A 10,742 MD-10,742 ND;NIA 12.Attachments: Description Summary of Proposal El 13.Well Class after proposed work: Detailed Operations Program n BOP Sketch n Exploratory n Stratigraphicn Development n •Service n 14.Estimated Date for 15.Well Status after proposed work: Commencing Operations: 09/04/13 Oil 111 . 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 Stan Pothole Phone: 907-777-8412 Email soorhola(c hilcoro.com Printed Name Stan Porhola Title Operations Engineer VI://Signature le Phone 907-777-8412 Date 3 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: '" 3- 4{.10.-k._ Plug Integrity ❑ BOP Test Try Mechanical Integrity Test ❑ Location Clearance ❑ Other: �� -I- 3000 ,05 c. �vr res it�f / . / / /J !� o r/0w t 4-- re-c. ...._. rr�� � �-C� W TjtGSSce� Spacing Exception Required? Yes ❑ No ❑ Subsequent Form Required: /v - II OLf R&M` OCT 1 0 2013\- APPROVED BY 7?,Approved by:,9 / COMMISSIONER THE COMMISSION Date: 45 it"�! [ NnAhh 3 Submit Form and `') ' Form 10-403(Revised 10/2012) Approved app r s r f r from a date of approval/0'... .- /Att ments in Duplicate ) • • Well Prognosis Well: SRU 331-27 Hilcorp Alaska,LL Date:8/26/2013 Well Name: SRU 331-27 API Number: 50-133-10156-00 Current Status: Gaslifted Oil Well Leg: N/A Estimated Start Date: September 4th, 2013 Rig: Cloverleaf#4 Reg.Approval Req'd? 403 Date Reg.Approval Rec'vd: Regulatory Contact: Donna Ambruz 777-8305 Permit to Drill Number: 100-148 First Call Engineer: Stan Porhola (907)777-8405 (0) (907)229-4824(M) Second Call Engineer: Chad Helgeson (907)777-8405(0) (907)229-4824(M) AFE Number: Current Bottom Hole Pressure: —3,117 psi @ 10,841' ND (Static survey April 2012 mid pert of 10,841' MD) Maximum Expected BHP: —3,117 psi @ 10,841' ND (Static survey April 2012 mid perf of 10,841' MD) Max.Allowable Surface Pressure: —0 psi (Based on actual reservoir conditions and min water cut of 50% (0.385psi/ft) will balance reservoir pressure at 2,745 ft. ND. Brief Well Summary This well was drilled and completed as an oil well in Hemlock benches H-4, H-5, & H-10 in 1958.A workover performed in 1963 isolated the H-10 and reperforate the H-4& H-5 zones.A workover in 1971 converted the well to gas injection. Gas injection was halted in 1981 and the well remained shut in until 2012.A workover performed in 2012 was performed to pull tubing and packers,cement squeeze the H-4 and H-5, pressure test casing, drill out cement, pressure test squeeze,cleanout fill, BPs, perforate H-6, H-7, and H-10 and ran a GL completion.The gaslift completion was pulled and converted to ESP completion in mid-July 2013. Upon initial startup of the ESP,a downhole failure occurred.The ESP was pulled and found to have a downhole pump failure (yet to be determined).The gaslift completion was re-ran to put the well back on production until a new ESP pump can be delivered.A capillary string was installed in early August 2013 to help with existing emulsion issues. Plan is to pull the gaslift completion again and run a new ESP. Notes Regarding Wellbore Condition • Well currently on gaslift.Surface facilities installed for ESP. Work-Over Rig Procedure 1. MIRU Cloverleaf#4 pulling unit. 2. MIRU slickline, PT lubricator to 1,500 psi Hi 250 Low 3. RIH and pull lower gaslift valve. POOH. RD slickline. 4. RU and pump+/-50 bbl Produced Water down tubing to clean pipe. Bleed casing pressure. 5. Set TWC in tubing hanger, ND tree, NU 7-1/16" BOPE and test to 250psi low/3,000psi high, annular to 250psi low/1,500psi high (hold each valve and test for 10-min). Record accumulator pre-charge pressures. a. Notify AOGCC 24hrs in advance to witness test. b. Notify BLM 48 hrs in advance of BOP test. c. Crew will be working 12hr shifts and well will be secured nightly with TIW valves and BOPE. 6. Release test pressure, pull TWC and install handling sub in hanger. • • Well Prognosis Well: SRU 331-27 Hilcorp Alaska,LL, Date:8/26/2013 7. Back out tbg hanger hold down pins and pick up on hanger. 8. RU to pull tubing hanger and unseat Arrowset AS1-X packer at 10,742' (right-hand release)and SOOH with 3-1/2" EUE 8RD production tubing from 10,817'.Jar tubing hanger and packer loose if necessary. a. If unable to unseat packer, RIH with E-line and use radial cutting torch to cut 3-1/2"tubing at+/- 10,735' (above On/Off tool and Packer). b. SOOH with tubing and RIH with overshot and jars and pull AS1-X packer. 9. SOOH w/all tubing. a. Keep 3 GLM to re-run with ESP completion. b. Send Packer and On/Off Tool to Tripoint for redress. 10. RIH with ESP with existing 3-1/2" 8rd EUE L-80 tubing. a. Test control lines to 2,500 psi. b. RU Pollard to use SS bands on tubing(ensure adequate banding material). c. Set 3 re-run GLMs at+/- 10,450',+/-7,500',and+/-4,500'. d. Run ESP cable around Minor OD of the GLMs(will not fit across Major OD). e. Have 3-6 joints of 3-1/2" EUE 8RD to reach a planned set depth of+/-10,600'. 11. Set base of ESP at+/-10,750' (Pump intake around+/- 10,660'). Land tubing hanger. 12. Set BPV, ND BOPs, NU Tree,test tree to 3,000 psi. a. Note: Rated pressure of BIW penetrator(wellhead to cable connection) is 3,000 psi. 13. RDMO workover rig and equipment. 14. Turn well over to production. 15. Notify AOGCC to conduct a no floes w test on the well after it has flowed for 5 days at a stable production. Attachments: 1. As-built Schematic 2. Proposed Schematic 3. BOP Schematic • • Swanson River Unit _ , -, , Well: SRU 331-27 ACTUAL SCHEMATIC Completion Ran: 8/04/2013 Hilcorp Alaska,LLC PTD# 100-148 API: 50-133-10156-00 RKB:272'/GL:257'AMSL Casing Detail KB-THF:15.0' Size Type Wt Grade ID Top Btm Hole Cmt Cmt Top 20" 1 `" 4+ 20" Conductor Surf 22' unknown Surf. 22' 18-%" 13-%" Surface 54.5 J-55 12.615 Surf 1,490' 1,500 sx Surf. 1,497' 7" 29 P-110 6.184 Surf 1,027' 12-1A' 444:74 g.;13-3/8" ! 7" 29 N-80 6.184 1,027' 2,172' 10-%" 1,490' 2 ' Prod Csg 11,659' 1,000 sx 9,140'CBL 7" 26 N-80 6.276 2,172' 8,192' 3 AIR i 7" 29 N-80 6.184 8,192' 10,695' II7" 29 P-110 6.184 10,695' 11,620' 4 IMP ' Tubing Detail Thread Cplg OD II3.5" 9.3 L-80 2.992 Surface 10,817' EUE 8RD 4.500" 5 i II Jewelry Detail 6 No. Depth ID OD Item i 1 17 2.992" 7" Tubing Hanger w/IBT x 8rd EUE XO 7 it II2 2,187' 2.867" 5.313" Gaslift Mandrel,Camco MM,Port 12 8 i 3 4,181' 2.867" 5.313" Gaslift Mandrel,Camco MM,Port 12 CBLTOC 9 11 4 5,784' 2.867" 5.313" Gaslift Mandrel,Camco MM,Port 12 1St 1' 9,140' .s C.,. e, * II 5 6,945' 2.867" 5.313" Gaslift Mandrel,Camco MM,Port 2 12 10 ? 6 7,786' 2.867" 5.313" Gaslift Mandrel,Camco MM,Port 12 II MI rwi 7 8,374' 2.867" 5.313" Gaslift Mandrel,Camco MM,Port 16 it y, r' 11 A F. p qi. 8 8,961' 2.867" 5.313" Gaslift Mandrel,Camco MM,Port 16 I 0_41 9 9,550' 2.867" 5.313" Gaslift Mandrel,Camco MM,Port 16 12 7 .��s` 10 10,139' 2.867" 5.313" Gaslift Mandrel,Camco MM,Port 16 ir 0 11 10,696' 2.867" 5.313" Gas Lift Orifice,Port Size 20 13 *" I a i„, I *' 12 10,740' 2.813" 5.910" On/Off Tool,w/X-Nipple ' 13 10,742' 3.000" 5.875" Packer Arrowset AS1-X Mech. I 14 10,784' 2.813" 4.500" X Nipple 14 1,,; 15 10,816' 3.000" 4.500" WLEG 4 wS0 16 11,077' Cement Retainer,Capped w/10 sx cement V° Ili 1 " ' H-4 Perforation History a 15 Date Zone Top(MD) Btm(MD) Top(MD) Btm(MD) Amt spf Comments H-5 12/11/58 WSO 10,795' 10,796' 10,795' 10,796' 1' 4 t 12/14/58 H-4 10,804' 10,836' 10,804' 10,836' 32' 4 WSO 12/14/58 H-5 10,849' 10,878' 10,849' 10,878' 29' 4 :,.. H-6 12/11/58 WSO 10,880' 10,881' 10,880' 10,881' 1' 4 " - h 8/31/2012 H-6 10,906' 10,916' 10,906' 10,916' 10' 6 2.5"Owen fs, H-7 Milled K 8/31/2012 H-7 10,926' 10,948' 10,926' 10,948' 22' 6 2.5"Owen retainer to H-10 12/09/58 Hemlock 11,038' 11,060' 11,038' 11,060' 22' 4 Open 11,077' Hemlock 8/31/2012 H-10 11,050' 11,076' 11,050' 11,076' 26' 6 2.5"Owen 16 . 12/07/58 Hemlock 11,185' 11,195' 11,185' 11,195' 10' 4 Isolated 7" - -Hemlock Capillary String Installed 8/13/2013 11,620' 3/8" 2205 Stainless Steel(11,731'spool) -„ti Top Bottom TD=12,046' PBTD=11,077' MD 0' 10,800' TVD 0' 10,800' Downhole Revised:8/13/13 Updated by STP 08/15/13 • • • Soldotna Creek Unit Well: SRU 331-27 PROPOSED SCHEMATIC Proposed Completion Hilcoru Alaska,LLC PTD: 100-148 API: 50-133-10156-00 RKB:272'/GL:257'AMSL Casing Detail KB-THF:15.0' w,Y 1 Size Type Wt Grade ID Top Btm Hole Cmt Cmt Top 20" Conductor Surf 22' unknown Surf. 20"e 22' '" 18-%" 13-% Surface 54.5 J-55 12.615" Surf 1,490' 1,500 sx Surf. 4 r 1,497' go 7" 29 P-110 6.184" Surf 1,027' 2 5 13-3/8" 7" 29 N-80 6.184" 1,027' 2,172' 10-%" 1,490' Prod Csg 11,659' 1,000 sx 9,140'CBL 7" 26 N-80 6.276" 2,172' 8,192' 7" 29 N-80 6.184" 8,192' 10,695' 7" 29 P-110 6.184" 10,695' 11,620' Tubing Detail Cplg OD 3.5" EUE 8RD 9.3 L-80 2.992" Surface 10,750' 4° 4.500" 2 ri Jewelry Detail No. Depth ID OD Item 1 17' 2.992" 6.184" Tubing Hanger w/8RD Box Down(8RD Pin Up on Full Jt Below) 3 2 4,500' 2.992" 5.313" Gaslift Mandrel,Camco MM,Dummy Valve 3 7,500' 2.992" 5.313" Gaslift Mandrel,Camco MM,Dummy Valve CBLTOC . 4 10,450' 2.992" 5.313" Gaslift Mandrel,Camco MM,Dummy Valve 9,140' 5 10,750' 4.560" ESP,456 series Motors/400 series Pumps 6 11,077' Cement Retainer,Capped w/10 sx cement 4 i fliii tilt it•ir 1r' liAl it 0 1 5 wso b�� ,s H-4 Perforation History 51 '; H_5 Date Zone Top(MD) Btm(MD) Top(MD) Btm(MD) Amt spf Comments '° 12/11/58 WSO 10,795' 10,796' 10,795' 10,796' 1' 4 wS0 12/14/58 H-4 10,804' 10,836' 10,804' 10,836' 32' 4 Squeezed - H-6 12/14/58 H-5 10,849' 10,878' 10,849' 10,878' 29' 4 Squeezed j 12/11/58 WSO 10,880' 10,881' 10,880' 10,881' 1' 4 H-7 Milled K 8/31/2012 H-6 10,906' 10,916' 10,906' 10,916' 10' 6 2.5"Owen retainer r to H-10 8/31/2012 H-7 10,926' 10,948' 10,926' 10,948' 22' 6 2.5"Owen 11,077' Hemlock 12/09/58 Hemlock 11,038' 11,060' 11,038' 11,060' 22' 4 Open 6 I, x t 8/31/2012 H-10 11,050' 11,076' 11,050' 11,076' 26' 6 2.5"Owen i , 12/07/58 Hemlock 11,185' 11,195' 11,185' 11,195' 10' 4 Isolated 7„ S -Hemlock 11,620' ..Y,,,,.rota TD=12,046' PBTD=11,077' Downhole Proposed Revised By STP 8/26/2013 • Swanson River 2013 Cloverleaf Rig 4 Knight Oil Tools BOP t1iMnrp alaNkn. AD 111 III lil III III tit to 1 1 2.57' Shaffer 7 1/16 5000 1 VITinu IT� 2 3/8-3 1/2 variable CAMERON 3.68' ` = '�- 1� �: IEEE Blind 7 1/16 5000 ■ • iii tit it/ iii Choke and Kill valves are 2 1/16 10M 1.56 _� 7 1 16 5000 • � r. �� it �� i ■ ' i '�IiLOI■ � 1 i 1■1i1■Itld11.111 " STATE OF ALASKA ALAR OIL AND GAS CONSERVATION COMMA N REPORT OF SUNDRY WELL OPERATIONS AL1G 2 7 2013 1. Operations Abandon H Repair Well Li Plug Perforations Perforate Lj Other L/j Capstring Install Performed: Alter Casing ❑ Pull Tubing ❑ Stimulate - Frac ❑ Waiver ❑ Time Extension ❑ Change Approved Program ❑ Operat. Shutdown ❑ Stimulate - Other ❑ Re-enter Suspended Well ❑ 2. Operator 4. Well Class Before Work: 5. Permit to Drill Number: Name: Hilcorp Alaska, LLC Development Q Exploratory ❑ Stratigraphic ❑ Service ❑ 100-148 3. Address: 3800 Centerpoint Drive, Suite 100 6. API Number: Anchorage, Alaska 99504 50-133-10156-00 7. Property Designation (Lease Number): 8. Well Name and Number: FEDA028406 Swanson River Unit (SRU) 331-27 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pool(s): N/A Swanson River Field / Hemlock Oil 11. Present Well Condition Summary: Total Depth measured 12,046 feet • Plugs measured 11,077 feet true vertical 12,046 feet Junk measured N/A feet Effective Depth measured 11,077 feet Packer measured N/A feet true vertical 11,077 feet true vertical N/A feet Casing Length Size MD TVD Burst Collapse Structural Conductor 22' 20" 22' 22' Surface 1,490' 13-3/8" 1,490' 1,490' 2,730 psi 853 psi Intermediate Production 11,620' 7" 11,620' 11,620' 604 psi 7,240 psi Liner SEp 2 5 2013 schw4E® Perforation depth Measured depth See Attached Schematic True Vertical depth See Attached Schematic Tubing (size, grade, measured and true vertical depth) 3-1/2" L-80 10,817' MD 10,817' TVD Arrowset 10,742' MD Packers and SSSV (type, measured and true vertical depth) AS1-X Mech 10,742' TVD N/A N/A 12. Stimulation or cement squeeze summary: N/A Intervals treated (measured): N/A Treatment descriptions including volumes used and final pressure: N/A 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 168 28 275 300 1250 Subsequent to operation: 152 13 260 200 1180 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run N/A Exploratory ❑ Development ❑✓ Service ❑ Stratigraphic ❑ Daily Report of Well Operations X 16. Well Status after work: Oil 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: 313-430 Contact Stan Porhola Email S orhola(Whilcorq.com Printed Name Stan Porhola Title Operations Engineer Date 9 2_6� Signature v J L Phone 907-777-8412 y•�G •�3 Form 10-404 Revised 10/2012 RBDMS SEN - 4 Submit Original Only 1�J Hilcorp Alaska, LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date SRU 331-27 50-133-10156-00 1 100-148 8/13/13 8/13/13 Daily Operations: 08/13/2013 -Tuesday Rig Up Cap String Truck. Rig up lubricator and adapter. Test to 3,000 psi. RIH w/ 3/8" capillary string. Set capillary string @ 10,800'. RDMO Cap String Truck. 20' 22 13-2, 1,41 CBI 9,: Millei retair to 11,07 • 13ilcorp Alaska, LLC RKB: 272'/ GL: 257' AMSL KB - THF: 15.0' TD = 12,046' 0 ACTUAL SCHEMATIC Casine Detail Swanson River Unit Well: SRU 331-27 Completion Ran: 8/04/2013 PTD# 100-148 API: 50-133-10156-00 Size Type Wt Grade ID Top Btm Hole Cmt Cmt Top 20" Conductor - - - Surf 22' 2.867" unknown Surf. 13-%" Surface 54.5 J-55 12.615 Surf 1,490' 2.867" 1,500 sx Surf. 1,497' 7" Prod Csg 29 P-110 6.184 Surf 1,027' , 2-Y4 11 2,725' 1,000 sx 9,140' CBL 7" 29 N-80 6.184 1,027' 2,172' 10-%" 11,659' 7" 26 N-80 6.276 2,172' 8,192' 7" 29 N-80 1 6.184 8,192' 10,695' 7" 29 P-110 1 6.184 10,695' 11,620' Tubing Detail Thread Cplg OD 3.5" 9.3 L-80 1 2.992 Surface 10,817' EUE 8RD 4.500" D flock 1pwplry Dp_tall No. Depth ID OD Item 1 17 2.992" 7" Tubing Hanger w/ IBT x 8rd EUE XO 2 2,187' 2.867" 5.313" Gaslift Mandrel, Camco MM, Port 12 3 4,181' 2.867" 5.313" Gaslift Mandrel, Camco MM, Port 12 4 1 5,784' 2.867" 5.313" Gaslift Mandrel, Camco MM, Port 12 5 6,945' 2.867" 5.313" Gaslift Mandrel, Camco MM, Port 12 6 7,786' 2.867" 5.313" Gaslift Mandrel, Camco MM, Port 12 7 8,374' 2.867" 5.313" Gaslift Mandrel, Camco MM, Port 16 8 8,961' 2.867" 5.313" Gaslift Mandrel, Camco MM, Port 16 9 9,550' 2.867" 5.313" Gaslift Mandrel, Camco MM, Port 16 10 1 10,139' 2.867" 5.313" Gaslift Mandrel, Camco MM, Port 16 11 10,696 2.867" 1 5.313" Gas Lift Orifice, Port Size 20 12 10,740' 2.813" 5.910" On/ Off Tool, w/ X -Nipple 13 10,742' 3.000" 5.875" Packer Arrowset AS1-X Mech. 14 10,784' 2.813" 4.500" X Nipple 15 10,816' 3.000" 4.500" WLEG 16 11,077' - - Cement Retainer, Capped w/ 10 sx cement Perforation History Date Zone Top(MD) Btm(MD) Top(MD) Btm(MD) Amt spf Comments 12/11/58 WSO 10,795' 10,796' 10,795' 10,796' 1' 4 12/14/58 H-4 10,804' 10,836' 10,804' 10,836' 32' 4 12/14/58 H-5 10,849' 10,878' 10,849' 10,878' 29' 4 12/11/58 WSO 10,880' 10,881' 10,880' 10,881' 1' 4 8/31/2012 H-6 10,906' 10,916' 10,906' 10,916' 10' 6 2.5" Owen 8/31/2012 H-7 10,926' 10,948' 10,926' 10,948' 22' 6 2.5" Owen 12/09/58 Hemlock 11,038' 11,060' 11,038' 11,060' 22' 4 Open 8/31/2012 H-10 11,050' 11,076' 11,050' 11,076' 26' 6 2.5" Owen 12/07/58 Hemlock 11,185' 11,195' 11,185' 11,195' 10' 4 Isolated flock Capillary String Installed 8/13/2013 3/8" 2205 Stainless Steel (11,731' spool) Top Bottom PBTD = 11,077' MD 0' 10,800' TVD 0' 10,800' Downhole Revised: 8/13/13 Updated by STP 08/15/13 THE STATE Of L KA GOVERNOR SEAN PARNELL 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 Stan Porhola gomED SEP 2 0 2013 Operations Engineer Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 100 } Anchorage, AK 99503 1 Re: Swanson River Field, Hemlock Oil Pool, SRU 331-27 Sundry Number: 313-430 Dear Mr. Porhola: 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, Cathy P. Foerster Chair DATED this /2 a y of August, 2013. Encl. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 AUG 072013 GC 1. Type of Request: Abandon ❑ Plug for Redril ❑ Perforate New Pod ❑ Repair WeN❑ Change Approved Program ❑ Suspend ❑ Plug Perforations ❑ Perforate ❑ Pull Tubing❑ Time Extension ❑ Operations Shutdowt ❑ Re-enter Susp. Wel ❑ Stimulate ❑ Alter Casing❑ Other. Cap String Install ❑✓ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number. Hilcorp Alaska, LLC Exploratory ❑ Development ❑✓ Stratigraphic ❑ Service ❑ 100-148 - 3. Address: 3800 Centerpoint Drive, Suite 100 6. API Number. Anchorage, Alaska 99503 50-13310156-00 , 7. If perforating: 8. Wel Name and Number: What Regulation or Conservation Order governs well spacing in this pool? CO 123A Will planned perforations require a spacing exception? Yes ❑ No ❑✓ Swanson River Unit (SRU)331-27 9. Property Designation (Lease Number): 10. Field/Pool(s): FEDA028406 Swanson River Field / Hemlock ON - 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): 12,046 12,046 11,077 1 11,077 1 11,077' N/A Casing Length Size MD TVD Burst Collapse Structural Conductor 22' 20" 22' 27 Surface 1,490' 13-3/8" 1,490' 1,490' 2,730 psi 853 psi Intermediate Production 11,620' 7" 11,620' 11,620' 605 psi 7,240 psi Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MID (ft): See Attached Schematic See Attached Schematic 3-1/2" 9.31E / L-80 10,817' Packers and SSSV Type: Packers and SSSV MD (t) and TVD (ft): AS1-X Ret Production Packer; N/A 10,742' MD/TVD; N/A 12. Attachments: Description Summary of Proposal ❑✓ 13. Well Class after proposed work: Detailed Operations Program BOP Sketch n Exploratory n Stratigraphicn Development n Service n 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: 08/12/13 Oil ❑✓ Gas ❑ WINJ ❑ GINJ ❑ WDSPL ❑ Suspended ❑ WAG ❑ Abandoned ❑ 16. Verbal Approval: Date: Commission Representative: GSTOR ❑ SPLUG ❑ 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Stan Panda Phone: 907-777-8412 Email s orho lCor . Printed Name Stan Porholaa Title Operations Engineer Signature Phone 907-777-8412 Date 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: / APPROVED BY COMMISSIONER THE COMMISSION / Date: 9 —12 — 3 Approved by:W"It4 /:1 l Q� j'V N ALprovae vsedPoi�nt�) Appro e r r onths from the to of approval. Submit Form and n� \� AOehments� to G . MCorp Alaska, LL' Well Prognosis Well: SRU 331-27 Date: 8/07/2013 Well Name: SRU 331-27 API Number: 50-133-10156-00 Current Status: Gaslifted Oil Well Leg: N/A Estimated Start Date: August 12th, 2013 Rig: Williams #405 Reg. Approval Req'd? 403 Date Reg. Approval Rec'vd: Regulatory Contact: Donna Ambruz 777-8305 Permit to Drill Number: 100-148 First Call Engineer: Stan Porhola (907) 777-8405 (0) (907) 229-4824 (M) Second Call Engineer: Chad Helgeson (907) 777-8405 (0) (907) 229-4824 (M) AFE Number: Current Bottom Hole Pressure: Maximum Expected BHP: Max. Allowable Surface Pressure: Brief Well Summary 3,117 psi @ 10,841' TVD 3,117 psi @ 10,841' TVD 0 psi (Static survey April 2012 mid perf of 10,841' MD) (Static survey April 2012 mid pert of 10,841' MD) (Based on actual reservoir conditions and min water cut of 50% (0.385psi/ft) will balance reservoir pressure at 2,745 ft. TVD. This well was drilled and completed as an oil well in Hemlock benches H-4, H-5, & H-10 in 1958. A workover performed in 1963 isolated the H-10 and reperforate the H-4 & H-5 zones. A workover in 1971 converted the well to gas injection. Gas injection was halted in 1981 and the well remained shut in until 2012. A workover performed in 2012 was performed to pull tubing and packers, cement squeeze the H-4 and H-5, pressure test casing, drill out cement, pressure test squeeze, cleanout fill, BPs, perforate H-6, H-7, and H-10 and ran a GL completion. The gaslift completion was pulled and converted to ESP completion in mid-July 2013. Upon initial startup of the ESP, a downhole failure occurred. The ESP was pulled and found to have a downhole pump failure (yet to be determined). The gaslift completion was re -ran to put the well back on production until a new ESP pump can be delivered. A capillary string is proposed to be installed to help with existing emulsion issues. Notes Regarding Wellbore Condition Re -ran gaslift completion in early August 2013. Completion procedure: 1. MIRU Cap String Truck, PT lubricator to 3,000 psi Hi 250 Low. 2. PU 3/8" capillary string. RIH and set at +/-10,800'. 3. Set spool of remaining line near well. 4. Rig down Cap String Truck. 5. Turn well over to production. Attachments: 1. Actual Schematic 2. Proposed Schematic 20' 22 13-3 1,4' CBL 9,: Millec retain to 11,07 Hilcorp Alaska, LLC RKB: 272'/ GL: 257' AMSL KB — TH F: 15.0' • • ACTUAL SCHEMATIC Casine Detail Swanson River Unit Well: SRU 331-27 Completion Ran: 8/04/2013 PTD# 100-148 API: 50-133-10156-00 Size Type Wt Grade ID Top Btm Hole Cmt Cmt Top 20" Conductor - - - Surf 22' - unknown Surf. 13-%" Surface 54.5 J-55 12.615 Surf 1,490' 18-%" 1,500 sx Surf. 1,497' 7" Prod Csg11,659' 29 P-110 6.184 Surf 1,027' 12 2,725' 1,000 sx 9,140' CBL 7" 29 N-80 6.184 1,027' 2,172' 10-%" 7" 26 N-80 6.276 2,172' 8,192' 7" 29 N-80 6.184 8,192' 10,695' 7" 29 P-110 1 6.184 10,695' 11,620' Tubing Detail Thread Cplg OD 3.5" 9.3 L-80 1 2.992 Surface 10,817' 1 JEUE8RD 1 4.500" 1104 TD = 12,046' PBTD = 11,077' Downhole Revised: 8/04/13 Jeweiry Detail No. Depth ID OD Item 1 17 2.992" 7" Tubing Hanger w/ IBT x 8rd EUE XO 2 2,187' 2.867" 5.313" Gaslift Mandrel, Camco MM, Port 12 3 4,181' 2.867" 5.313" Gaslift Mandrel, Camco MM, Port 12 4 5,784' 2.867" 5.313" Gaslift Mandrel, Camco MM, Port 12 5 6,945' 2.867" 5.313" 1 Gaslift Mandrel, Camco MM, Port 12 6 7,786' 2.867" 5.313" Gaslift Mandrel, Camco MM, Port 12 7 8,374' 2.867" 5.313" Gaslift Mandrel, Camco MM, Port 16 8 1 8,961' 2.867" 5.313" Gaslift Mandrel, Camco MM, Port 16 9 9,550' 2.867" 5.313" Gaslift Mandrel, Camco MM, Port 16 10 10,139' 2.867" 5.313" Gaslift Mandrel, Camco MM, Port 16 11 10,696' 2.867" 5.313" 1 Gas Lift Orifice, Port Size 20 12 10,740' 2.813" 5.910" On/ Off Tool, w/ X -Nipple 13 10,742' 3.000" 5.875" Packer Arrowset AS1-X Mech. 14 10,784' 2.813" 4.500" X Nipple 15 10,816' 3.000" 4.500" WLEG 16 11,077' - - Cement Retainer, Capped w/ 10 sx cement Perforation History Date Zone Top(MD) Btm(MD) Top(MD) Btm(MD) Amt spf Comments 12/11/58 WSO 10,795' 10,796' 10,795' 10,796' 1' 4 12/14/58 H-4 10,804' 10,836' 10,804' 10,836' 32' 4 12/14/58 H-5 10,849' 10,878' 10,849' 10,878' 29' 4 12/11/58 WSO 10,880' 10,881' 10,880' 10,881' 1' 4 8/31/2012 H-6 10,906' 10,916' 10,906' 10,916' 10' 6 2.5" Owen 8/31/2012 H-7 10,926' 10,948' 10,926' 10,948' 22' 6 2.5" Owen 12/09/58 Hemlock 11,038' 11,060' 11,038' 11,060' 22' 4 Open 8/31/2012 H-10 11,050' 11,076' 11,050' 11,076' 26' 6 2.5" Owen 12/07/58 THemlock 11,185' 11,195' 11,185' 11,195' 10' 4 Isolated Updated by STP 08/06/13 • •f Hileorp Alaska, LLC RKB: 272'/ GL: 257' AMSL KB —THF: 15.0' 20 22 13-: 1,4 CBL 9,: Mille( retain to 11,07 0 PROPOSED SCHEMATIC Casine Detail Swanson River Unit Well: SRU 331-27 Proposed Completion PTD# 100-148 API: 50-133-10156-00 Size Type Wt Grade ID Top Btm Hole Cmt Cmt Top 20" Conductor - 5.313" - Surf 22' - unknown Surf. 13-%" Surface 54.5 J-55 12.615 Surf 1,490' 18-%" 1,500 sx Surf. 1,497' 7" Prod Csg 29 P-110 6.184 Surf 1,027' 12-%" 2,725' 1,000 sx 9,140' CBL 7" 29 N-80 6.184 1,027' 2,172' 10-%" 11,659' 7" 26 N-80 6.276 2,172' 8,192' 7" 29 N-80 6.184 8,192' 10,695' 7" 29 P-110 6.184 10,695' 11,620' Tubing Detail Thread Cplg OD 3.5" 1 9.3 1 L-80 1 2.992 Surface 10,817' EUE 8RD 4.500" TD =12,046' PBTD = 11,077' Jewelry Detail No. Depth ID CID Item 1 17 2.992" 7" Tubing Hanger w/ IBT x 8rd EUE XO 2 2,187' 2.867" 5.313" Gaslift Mandrel, Camco MM, Port 12 3 4,181' 2.867" 5.313" Gaslift Mandrel, Camco MM, Port 12 4 1 5,784' 2.867" 1 5.313" Gaslift Mandrel, Camco MM, Port 12 5 6,945' 2.867" 1 5.313" Gaslift Mandrel, Camco MM, Port 12 6 7,786' 2.867" 5.313" Gaslift Mandrel, Camco MM, Port 12 7 8,374' 2.867" 5.313" Gaslift Mandrel, Camco MM, Port 16 8 8,961' 2.867" 5.313" Gaslift Mandrel, Camco MM, Port 16 9 9,550' 2.867" 5.313" Gaslift Mandrel, Camco MM, Port 16 10 10,139' 2.867" 5.313" Gaslift Mandrel, Camco MM, Port 16 11 10,696' 2.867" 5.313" 1 Gas Lift Orifice, Port Size 20 12 10,740' 2.813" 5.910" On/ Off Tool, w/ X -Nipple 13 10,742' 3.000" 5.875" Packer Arrowset AS1-X Mech. 14 10,784' 2.813" 4.500" X Nipple 15 10,816' 3.000" 4.500" WLEG 16 11,077' - - Cement Retainer, Capped w/ 10 sx cement Perforation History Date Zone Top(MD) Btm(MD) Top(MD) Btm(MD) Amt spf Comments 12/11/58 WSO 10,795' 10,796' 10,795' 10,796' 1' 4 12/14/58 H-4 10,804' 10,836' 10,804' 10,836' 32' 4 12/14/58 H-5 10,849' 10,878' 10,849' 10,878' 29' 4 12/11/58 WSO 10,880' 10,881' 10,880' 10,881' 1' 4 8/31/2012 H-6 10,906' 10,916' 10,906' 10,916' 10' 6 2.5" Owen 8/31/2012 H-7 10,926' 10,948' 10,926' 10,948'22' 6 2.5" Owen 12/09/58 Hemlock 11,038' 11,060' 11,038' 11,060' 22' 4 Open 8/31/2012 H-10 11,050' 11,076' 11,050' 11,076' 26' 6 2.5" Owen 12/07/58I Hemlock 11,185' 11,195' 11,185' 11,195' 10' 4 Isolated Capillary String Proposed to Install 3/8" 2205 Stainless Steel (11,731' spool) Top Bottom MD 0' 10,800' TVD 0' 10,800' Proposed Downhole Updated by STP 08/07/13 STATE OF ALASKA ALA OIL AND GAS CONSERVATION COMIM SION REPORT OF SUNDRY WELL OPERATIONS 'RECENED AUG 072013 1. Operations Abandon Li Repair Well 0 Plug Perforations Perforate U Other ✓ ESP Repair Performed: Alter Casing ❑ Pull Tubing [A 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 Q Stratigraphic❑ Exploratory ❑ Service ❑ 100-148 � 3. Address: 3800 Centerpoint Drive, Suite 100 6. API Number: Anchorage, Alaska 99504 50-133-10156-00 ' 7. Property Designation (Lease Number): 8. Well Name and Number: FEDA028406 Swanson River Unit (SRU) 331-27 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pool(s): N/A Swanson River Field / Hemlock Oil 11. Present Well Condition Summary: Total Depth measured 12,046 feet • Plugs measured 11,077 feet true vertical 12,046 feet Junk measured N/A feet Effective Depth measured 11,077 feet Packer measured N/A feet true vertical 11,077 feet true vertical N/A feet Casing Length Size MD TVD Burst Collapse Structural Conductor 22' 20" 22' 22' Surface 1,490' 13-3/8" 1,490' 1,490' 2,730 psi 853 psi Intermediate Production 11,620' 7" 11,620' 11,620' 604 psi 7,240 psi Liner Perforation depth Measured depth See Attached Schematic SCANNE'1VN AUG 12 2013 True Vertical depth See Attached Schematic Tubing (size, grade, measured and true vertical depth) 3-1/2" L-80 10,817' MD 10,817' TVD Arrowset 10,742' MD Packers and SSSV (type, measured and true vertical depth) AS1-X Mech 10,742' TVD N/A N/A 12. Stimulation or cement squeeze summary: N/A Intervals treated (measured): N/A Treatment descriptions including volumes used and final pressure: N/A 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 0 0 0 0 Subsequent to operation: 138 277 414 1,000 220 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run N/A Exploratory ❑ Development ❑✓ ' Service ❑ Stratigraphic ❑ Daily Report of Well Operations X 16. Well Status after worts: Oil ✓ - 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: 313-394 Contact Stan Porhola Email s orhola(ftilcorp.com Printed Name Stan Porhola Title Operations Engineer Signature �y Phone 907-777-8412 Date p b Form 10-404 Revised 10/2012 NUUM3 AUU Submit Original Only • • Hilcorp Alaska, LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date SRU 331-27 50-133-10156-00 100-148 8/1/13 8/4/13 Daily Operations: 08/01/2013 - Thursday Laid containment, MIRU WOR and equipment. Sealed in WOR and equipment. Set BPV and ND Prduction Tree, NU BOPS. Pulled BPV. Secured well and SDFN. 08/02/2013 - Friday Tested BOPE, Annular 250-1500psi, Rams 250-3,000psi, Valves 250-3,000psi. (Witness waived by Jim Regg, AOGCC.) Function tested Kommey and gas detection. Bled off csg pressure. Installed lifting joint and pulled tbg hanger. Did not find a short in the penetrator, power cable or pigtail splice. MIRU SLB/equipment, TOOH w/ 100 stands, dual encapsulated control line and power cable. Did find failures in cable. 08/03/2013 - Saturday TOOH w/67 stands of 3-1/2" EUE 9.3# 8RD tbg, 1/4" dual encapsulated control line and power cable. Tested for shorts. L/D ESP equipment and sent back to SLB for inspection. 08/04/2013 - Sunday TIH w/ 340 jts of 3-1/2" 9.3# EUE 8RD, 10 GLM, 3-1/2" X -nipple and WRG. Set packer at 10,742'. Had trouble setting packer at 10,774' so we L/D one jnt and set it. Landed tbg hanger and circulated well down csg. Broke circulation and tested csg to 1,500psi. Bled off csg and tested tbg to 1,500psi. Bled off tbg. Installed BPV and ND BOPS, NU PT. MIRU SL. RIH and pulled RHCP out. RDMO WOR. 20' 22 CBl 9,: Millei retair to 11,07 Hileorp Alaska, LLC # K RKB: 272'/ GL: 257' AMSL KB — TH F: 15.0' Downhole Revised: 8/04/13 • • ACTUAL SCHEMATIC Casing Detail Swanson River Unit Well: SRU 331-27 Completion Ran: 8/04/2013 PTD# 100-148 API: 50-133-10156-00 Size Type Wt Grade ID Top Btm Hole Cmt Cmt Top 20" Conductor - 5.313" - Surf 22' - unknown Surf. 13-%" Surface 54.5 J-55 12.615 Surf 1,490' 18-%" 1,500 sx Surf. 1,497' 7" Prod Csg 1 29 P-110 6.184 Surf 1,027' 12W 2,725' 1,000 sx 9,140' CBL 7" 29 N-80 6.184 1,027' 2,172' 10-%" 11,659' 7" 26 N-80 6.276 2,172' 8,192' 7" 29 N-80 6.184 8,192' 10,695' 7" 29 P-110 6.184 10,695' 11,620' Tubing Detail Thread Cplg OD 3.5" 9.3 L-80 1 2.992 Surface 1 10,817' EUE 8RD 4.500" 1106 177' Jewelry Detail No. Depth ID CID Item 1 17 2.992" 7" Tubing Hanger w/ IBT x 8rd EUE XO 2 2,187' 2.867" 5.313" Gaslift Mandrel, Camco MM, Port 12 3 4,181' 2.867" 5.313" Gaslift Mandrel, Camco MM, Port 12 4 5,784' 2.867" 5.313" Gaslift Mandrel, Camco MM, Port 12 5 1 6,945' 2.867" 1 5.313" Gaslift Mandrel, Camco MM, Port 12 6 7,786' 2.867" 5.313" Gaslift Mandrel, Camco MM, Port 12 7 8,374' 2.867" 5.313" Gaslift Mandrel, Camco MM, Port 16 8 8,961' 2.867" 5.313" Gaslift Mandrel, Camco MM, Port 16 9 9,550' 2.867" 5.313" Gaslift Mandrel, Camco MM, Port 16 10 10,139' 2.867" 5.313" Gaslift Mandrel, Camco MM, Port 16 11 1 10,696' 2.867" 5.313" Gas Lift Orifice, Port Size 20 12 10,740' 2.813" 5.910" On/ Off Tool, w/ X -Nipple 13 10,742' 3.000" 5.875" Packer Arrowset A51 -X Mech. 14 10,784' 2.813" 4.500" X Nipple 15 10,816' 3.000" 4.500" WLEG 16 11,077' - - Cement Retainer, Capped w/ 10 sx cement Perforation History Date Zone Top(MD) Btm(MD) Top(MD) Btm(MD) Amt spf Comments 12/11/58 WSO 10,795' 10,796' 10,795' 10,796' 1' 4 12/14/58 H-4 10,804' 10,836' 10,804' 10,836' 32' 4 12/14/58 H-5 10,849' 10,878' 10,849' 10,878' 29' 4 12/11/58 WSO 10,880' 10,881' 10,880' 10,881' 1' 4 8/31/2012 H-6 10,906' 10,916' 10,906' 10,916' 10' 6 2.5" Owen 8/31/2012 H-7 10,926' 10,948' 10,926' 10,948' 22' 6 2.5" Owen 12/09/58 Hemlock 11,038' 11,060' 11,038' 11,060' 22' 4 Open 8/31/2012 H-10 11,050' 11,076' 11,050' 11,076' 26' 6 2.5" Owen 12/07/58 Hemlock 11,185' 11,195' 11,185' 11,195' 10' 1 4 Isolated Updated by STP 08/06/13 0 9 Schwartz, Guy L (DOA) From: Stan Porhola <sporhola@hilcorp.com> Sent: Wednesday, July 31, 2013 3:22 PM To: Schwartz, Guy L (DOA) Cc: Donna Ambruz; Chad Helgeson; Wade Hudgens - (C) Subject: SRU 331-27 (PTD 100-148) Change Request Sundry 313-394 Attachments: SRU 331-27 Proposed Gaslift Schematic 7-31-13.doc Guy, Per our conversation, we are requesting verbal approval to start operations on well SRU 331-27 (PTD 100-148) under the sundry submittal (313-394). Based on our current progress with the Williams #405 Workover Rig, we expect to be able to move to SRU 331-27 as early as tomorrow (8/01/13). We are also requesting a change to the sundry (313-394) for well SRU 331-27 (PTD 100-148) to run a gaslift completion (see attached schematic) in the event the failure on the ESP is a downhole motor or pump failure (and not a cable failure). In this scenario, we would not replace the motor and pump as proposed in the sundry, but instead re -run the previously existing gaslift completion in this well. If the gaslift completion is run, we will use the ESP downhole equipment on well SRU 21-27 (PTD 161-010) and convert this well to ESP, as proposed under the approved sundry (313-352). The reasoning for this change is that we only have enough downhole ESP equipment currently to run into one well, and pending the results of a motor/pump tear down on the failed SRU 331-27 ESP, we will not run an ESP back into this well. Regards, Stan Porhola I Operations Engineer North Kenai Asset Team Hilcorp Alaska, LLC ,n Office:i (:o lio%id yyi�i EE 'r",)) _I_ OF 7W + w w. I %/s9 THE STATE Alaska ail and Gas " ,4 o 11111 - 1 LASKA Conservation CCommission r�, I GOVERNOR SEAN PARNELL 333 West Seventh Avenue mm+ Q. Anchorage, Alaska 99501-3572 ALAS Main: 907.279.1433 Fax: 907.276.7542 Stan Porhola p 0:1 LDS Operations Engineer C1A N NE Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 100 ' L Anchorage, AK 99503 10 0 t "I Re: Swanson River Field, Hemlock Oil Pool, SRU 331-27 Sundry Number: 313-394 Dear Mr. Porhola: 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, Cathy P. oerster Chair S DATED this I day of August, 2013. Encl. ,ti � . • • 4'' - RECEIVED STATE OF ALASKA JUL 073 ALASKA OIL AND GAS CONSERVATION COMMISSION OS g (/! APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 A00 CIL; 1.Type of Request: Abandon❑ Plug for Redril ❑ Perforate New Pod❑ Repair Well❑ Change Approved Program❑ Suspend❑ Plug Perforations❑ Perforate❑ Pull Tubing0 • Time Extension❑ Operations Shutdowi❑ Re-enter Susp.Wel ❑ Stimulate❑ Alter Casing❑ I Other. ESP Repair 0 2.Operator Name: r. Hilcorp Alaska,LLC 4.Current Well Class: 5.Permit to Drill Number Exploratory ❑ Development 0 . 100-148 ' 3.Address: 3800 Centerpoint Drive,Suite 100 Stratigraphic III Service ❑ 6.API Number. Anchorage,Alaska 99503 50-133-10156-00 • I 7.If perforating: 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? CO 123A Swanson River Unit(SRU)331-27 • Will planned perforations require a spacing exception? Yes ❑ No El 9.Property Designation(Lease Number): 10.Field/Pool(s): FEDA028406 Swanson River Field/Hemlock Oil = 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth ND(ft): Effective Depth MD(ft): Effective Depth ND(ft): Plugs(measured): Junk(measured): 12,046 ' 12,046 • 11,077 11,077 11,077' N/A Casing Length Size MD WI) Burst Collapse Structural Conductor 22' 20" 22' 22' Surface 1,490' 13-3/8" 1,490' 1,490' 2,730 psi 853 psi Intermediate Production 11,620' 7" 11,620' 11,620' 605 psi 7,240 psi Liner Perforation Depth MD(ft): Perforation Depth ND(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See Attached Schematic See Attached Schematic 3-1/2" 9.3#/L-80 10,750' Packers and SSSV Type: Packers and SSSV MD(t)and TVD(ft): N/A;N/A N/A;N/A 12.Attachments: Description Summary of Proposal 0 13.Well Class after proposed work: Detailed Operations Program n BOP Sketch n Exploratory n Stratigraphicn Development n Service n 14.Estimated Date for 15.Well Status after proposed work: Commencing Operations: 07/26/13 Oil IN • Gas ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: 7 3/-/3 WINJ ❑ GINJ ❑ WAG ❑ Abandoned ❑ Commission Representative: 6, 5L a r F+— GSTOR ❑ SPLUG El 17.I hereby certify that the foregoing is Krue and correct to the best of my knowledge. Contact Stan Porhola Phone: 907-777-8412 Email sDo rho].Q! pcorD.CQ Printed Name Stan Porhola Title Operations Engineer Signature ) Per/4,e\ Phone 907-777-8412 Date 7 24 /3 COMMISSION USE ONLY l� Conditions of approval: Notify Commission so that a representative may witness Sundry Number. ,31 '5^, / Plug Integrity ❑ BOP Test WI/ Mechanical Integrity Test I=1 Location Clearance ❑ [�U7 Other: if 3 �1� 0�� /.0.,-1. I� ,_ RBDMS AUG - 2 20 Spacing Exception Required? Yes ❑ No li Subsequent Form Required: /v—y 0l—( o! ../e47 ` APPROVED BY Approved by: , /y 4i•. — COMMISSIONER THE COMMISSION Date: #-/--/.3 n Lmonths 7.3/-/3 Submit Form and Form 10-403(Revised 10/2012) Appr v f n SC/r+r/nn a from date of approval. Attachmen Dupljcate t v • • • Well Prognosis Well: SRU 331-27 Hilcoru Alaska,LL Date:7/22/2013 Well Name: SRU 331-27 API Number: 50-133-10156-00 Current Status: Failed ESP Oil Well Leg: N/A Estimated Start Date: July 25th, 2013 Rig: Williams#405 Reg.Approval Req'd? 403 Date Reg.Approval Rec'vd: Regulatory Contact: Donna Ambruz 777-8305 Permit to Drill Number: 100-148 First Call Engineer: Stan Porhola (907)777-8405 (0) (907) 229-4824(M) Second Call Engineer: Chad Helgeson (907)777-8405 (0) (907) 229-4824(M) AFE Number: 1321774 Current Bottom Hole Pressure: —3,117 psi @ 10,841' ND (Static survey April 2012 mid perf of 10,841' MD) Maximum Expected BHP: —3,117 psi @ 10,841' ND (Static survey April 2012 mid perf of 10,841' MD) Max.Allowable Surface Pressure: —0 psi (Based on actual reservoir conditions and min water cut of 50% (0.385psi/ft) will balance reservoir pressure at 2,745 ft. ND. Brief Well Summary This well was drilled and completed as an oil well in Hemlock benches H-4, H-5,& H-10 in 1958.A workover performed in 1963 isolated the H-10 and reperforate the H-4& H-5 zones.A workover in 1971 converted the well to gas injection. Gas injection was halted in 1981 and the well remained shut in until 2012.A workover performed in 2012 was performed to pull tubing and packers,cement squeeze the H-4 and H-5, pressure test casing, drill out cement, pressure test squeeze,cleanout fill, BPs, perforate H-6, H-7, and H-10 and ran a GL completion.The gaslift completion was pulled and converted to ESP completion in mid-July 2013. Upon initial startup of the ESP,a downhole failure occurred which will require pulling the tubing to inspect the ESP and downhole cable. Notes Regarding Wellbore Condition • Failed ESP(Likely cable or motor failure). Work-Over Rig Procedure 1. MIRU Williams 405 pulling unit. • 2. Install back pressure valve in tbg hanger. Note: If hanger profile is not test worthy, call out slick line with tubin g stop/plug sto lu and set at 500'. 3. Set BPV in tubing hanger, ND tree, NU 7-1/16" BOPE and test to 250psi low/3.00Opsi high,annular • to 250psi low/1,500psi high (hold each valve and test for 5-min). Record accumulator pre-charge pressures. a. Notify AOGCC 24hrs in advance to witness test. b. Crew will be working 12hr shifts and well will be secured nightly with TIW valves and BOPE. 4. Release test pressure, pull tubing stop or BPV and install handling sub in hanger. 5. Back out tbg hanger hold down pins and pick up on hanger. 6. RU to pull tubing hanger and and SOOH with 3-1/2" production tubing down to 10,750'. a. Full joint of 3-1/2"8RD(Pinin Up located below hanger. in • • Well Prognosis Well: SRU 331-27 Hilcorp Alaska,LLB Date:7/22/2013 b. Inspect cable for damage. Replace cable if damaged. c. Inspect motors, seals,and pumps for damage. Replace if damaged. d. Send motors and protectors to ESP shop for redress if no damage. 7. RIH with existing or replacement ESP(depending on failure mechanism)with existing 3-1/2"8rd EUE L-80 tubing. Set ESP at+/-10,750'. Land tubing hanger. 8. Set BPV, ND BOPs, NU Tree,test tree to 3,000 psi. a. Note: Rated pressure of BIW penetrator(wellhead to cable connection) is 3,000 psi. 9. RDMO workover rig and equipment. 10. Turn well over to production. 11. Notify AOGCC to conduct a no flow test on the well after it has flowed for 5 days at a stable production. Attachments: 1. As-built Schematic 2. Proposed Schematic 3. BOP Schematic iSoldotna Creek Unit R Well: SRU 331-27 ACTUAL SCHEMATIC Completion Ran:7/13/2013 Hilcorp Alaska,LLC PTD: 100-148 API: 50-133-10156-00 RKB:272'/GL:257'AMSL KB-THF:15.0' Casing Detail �II �J Size Type Wt Grade ID Top Btm Hole Cmt Cmt Top 20" +�J.4, 1 20" Conductor Surf 22' unknown Surf. 5 „ 22' `' 13-,4" Surface 54.5 J-55 12.615" Surf 1,490' 18 / 1,500 sx Surf. 1,497' 7" 29 P-110 6.184" Surf 1,027' 12 ;, 2,725' 13-3/8"C' 7" 29 N-80 6.184" 1,027' 2,172' 10-%" 1,490' Prod Csg 11,659' 1,000 sx 9,140'CBL 7" 26 N-80 6.276" 2,172' 8,192' 7" 29 N-80 6.184" 8,192' 10,695' 7" 29 P-110 6.184" 10,695' 11,620' Tubing Detail Cplg OD 3.5" EUE 8RD 9.3 L-80 2.992" Surface 10,750' 4.500" Jewelry Detail No. Depth ID OD Item 1 17' 2.992" 6.184" Tubing Hanger w/8RD Box Down(8RD Pin Up on Full Jt Below) 2 10,750' - 4.560" ESP,456 series Motors/400 series Pumps 3 11,077' - - Cement Retainer,Capped w/10 sx cement CBL TOC 9,140' 0 0 0 0 r.711 M''-, y . 2 - ws0 r- H-4 Perforation History H-5 Date Zone Top(MD) Btm(MD) Top(MD) Btm(MD) Amt spf Comments 12/11/58 WSO 10,795' 10,796' 10,795' 10,796' 1' 4 - wS0 12/14/58 H-4 10,804' 10,836' 10,804' 10,836' 32' 4 Squeezed H-6 12/14/58 H-5 10,849' 10,878' 10,849' 10,878' 29' 4 Squeezed 12/11/58 WSO 10,880' 10,881' 10,880' 10,881' 1' 4 H-7 Milled K 8/31/2012 H-6 10,906' 10,916' 10,906' 10,916' 10' 6 2.5"Owen retainer to H-10 8/31/2012 H-7 10,926' 10,948' 10,926' 10,948' 22' 6 2.5"Owen 11,077' 777r- _;„....r_Hemlock 12/09/58 Hemlock 11,038' 11,060' 11,038' 11,060' 22' 4 Open 3 8/31/2012 H-10 11,050' 11,076' 11,050' 11,076' 26' 6 2.5"Owen 12/07/58 Hemlock 11,185' 11,195' 11,185' 11,195' 10' 4 Isolated 7. Hemlock 11,620' i. - TD=12,046' PBTD=11,077' Downhole Revised:7/13/2013 Revised By STP 7/20/2013 • H . • Soldotna Creek Unit .. Well: SRU 331-27 PROPOSED SCHEMATIC Proposed Completion I lileorp Alaska,LLC PTD: 100-148 API: 50-133-10156-00 RKB:272'/GL:257'AMSL KB-THF:15.0' Casing Detail �� Size Type Wt Grade ID Top Btm Hole Cmt Cmt Top I. 20" Conductor - - - Surf 22' - unknown Surf. s " 22 13-%s" Surface 54.5 J-55 12.615" Surf 1,490' 18-/ 1,500 sx Surf. 1,497' 7" 29 P-110 6.184" Surf 1,027' 12 %" 2,725' 13-3/8" _ 7" 29 N-80 6.184" 1,027' 2,172' 10-%" 1,490' Prod Csg - 11,659' 1,000 sx 9,140'CBL 7" 26 N-80 6.276" 2,172' 8,192' 7" 29 N-80 6.184" 8,192' 10,695' 7" 29 P-110 6.184" 10,695' 11,620' Tubing Detail Cplg OD 3.5" EUE 8RD 9.3 L-80 2.992" Surface 10,750' 4.500" Jewelry Detail No. Depth ID OD Item 1 17' 2.992" 6.184" Tubing Hanger w/8RD Box Down(8RD Pin Up on Full it Below) 2 10,750' 4.560" ESP,456 series Motors/400 series Pumps(Replace Failed Component(s) CBL 3 11,077' - - Cement Retainer,Capped w/10 sx cement 9,140' 0 0 0 0 0 0 F 2 - ws0 H-4 - Perforation History H-5 Date Zone Top(MD) Btm(MD) Top(MD) Btm(MD) Amt spf Comments 12/11/58 WSO 10,795' 10,796' 10,795' 10,796' 1' 4 - WSO 12/14/58 H-4 10,804' 10,836' 10,804' 10,836' 32' 4 Squeezed H-6 12/14/58 H-5 10,849' 10,878' 10,849' 10,878' 29' 4 Squeezed 12/11/58 WSO 10,880' 10,881' 10,880' 10,881' 1' 4 H-7 Milled K 8/31/2012 H-6 10,906' 10,916' 10,906' 10,916' 10' 6 2.5"Owen retainer - to H-10 8/31/2012 H-7 10,926' 10,948' 10,926' 10,948' 22' 6 2.5"Owen 11,077' Hemlock 12/09/58 Hemlock 11,038' 11,060' 11,038' 11,060' 22' 4 Open 3 �I_�-+.� 8/31/2012 H-10 11,050' 11,076' 11,050' 11,076' 26' 6 2.5"Owen 12/07/58 Hemlock 11,185' 11,195' 11,185' 11,195' 10' 4 Isolated 7" _ Hemlock 11,620' TD=12,046' PBTD=11,077' Proposed Downhole Revised By STP 7/22/2013 • Swanson River 2013 Williams Ri 405 g Knight Oil Tools BOP Ildcnrp t.tl. • • 111 111 III III III iii III ili 2.57' after 71/16 5000 III III ill lit Ill (III ,L Itl I11 2 3/8-31/2 variable CAMERON 3.68' :miew �I =1W: _ Blind mom. 11 71/16 5000 I I I I i i I I i l i t l i t Choke and Kill valves are 2 1/16 10M I 1U Lt 1 If , .VI 1.56' O'rn ' P 1:!!!:!n1F �;�, .,� '•0'/ I l l (1I nil I 1 i 111 : ��- " g • • Schwartz, Guy L (DOA) From: Schwartz, Guy L(DOA) Sent: Wednesday,July 31, 2013 3:45 PM To: 'Stan Porhola' Cc: Donna Ambruz;Chad Helgeson;Wade Hudgens - (C) Subject RE:SRU 331-27(PTD 100-148)Change Request Sundry 313-394 Stan, You have verbal approval to rig up on well SRU 331-27 and pull ESP . Pending diagnostics you may either re-run ESP or run the proposed GL design. Guy Schwartz Senior Petroleum Engineer AOGCC 907-444-3433 cell 907-793-1226 office From: Stan Porhola [niailto sporhola dhilcorp.c?rri.] Sent: Wednesday, July 31, 2013 3:22 PM To: Schwartz, Guy L(DOA) Cc: Donna Ambruz; Chad Helgeson; Wade Hudgens- (C) Subject: SRU 331-27 (PTD 100-148)Change Request Sundry 313-394 Guy, Per our conversation,we are requesting verbal approval to start operations on well SRU 331-27(PTD 100-148) under the sundry submittal (313-394). Based on our current progress with the Williams#405 Workover Rig,we expect to be able to move to SRU 331-27 as early as tomorrow(8/01/13). We are also requesting a change to the sundry(313-394)for well SRU 331-27 (PTD 100-148)to run a gaslift completion (see attached schematic) in the event the failure on the ESP is a downhole motor or pump failure (and not a cable failure). In this scenario,we would not replace the motor and pump as proposed in the sundry,but instead re-run the previously existing gaslift completion in this well. If the gaslift completion is run,we will use the ESP downhole equipment on well SRU 21-27 (PTD 161-010)and convert this well to ESP,as proposed under the approved sundry(313-352).The reasoning for this change is that we only have enough downhole ESP equipment currently to run into one well,and pending the results of a motor/pump tear down on the failed SRU 331-27 ESP,we will not run an ESP back into this well. Regards, Stan Porhola ; Operations Engineer North Kenai Asset Team Hilcorp Alaska,LLC Office: (907) 77743112 Mobile: i901 3 331..8228 1 • a LI 411 0 Swanson River Unit Well: SRU 331-27 PROPOSED SCHEMATIC Proposed Completion Nikon)Alaska,111€ Coot,f „j e„A ce7 PTD# 100-148 API: 50-133-10156-00 RKB:272'/GL:257'AMSL Casing Detail KB-THF:15.0' \---/ Size Type Wt Grade ID Top Btm Hole Cmt Cmt Top 20" J 1 L 20" Conductor - - - Surf 22' - unknown Surf. 22' 18-%" 13-%" Surface 54.5 1-55 12.615 Surf 1,490' 1,500 sx Surf. 1,497' 7" 29 P-110 6.184 Surf 1,027' 12-1/4" 2,725' 13-3/8" .. 2 7" 29 N-80 6.184 1,027' 2,172' 1 0-e9 1,490' ( Prod Csg 1,000 sx 9,140'CBL 7" 26 N-80 6.276 2,172' 8,192' 3 I ill 7" 29 N-80 6.184 8,192' 10,695' 7" 29 P-110 6.184 10,695' 11,620' 4 I 0 Tubing Detail Cpig OD 3.5" 9.3 L-80 2.992 Surface 10,791' 4.53" 5 I' i � 'r �1I 1 Jewelry Detail 6 No. Depth ID OD Item 7 I 131 1 17 2.992" 7" Tubing Hanger w/IBT x 8rd EUE XO 2 2,296' 2.867" 5.313" Gaslift Mandrel,Camco MM,Port 12 8 1 ii 3 4,223' 2.867" 5.313" Gaslift Mandrel,Camco MM,Port 12 CBLTOC 9 i 4 5,827' 2.867" 5.313" Gaslift Mandrel,Camco MM,Port 12 9,140' 5 7,021' 2.867" 5.313" Gaslift Mandrel,Camco MM,Port 12 10 6 7,833' 2.867" 5.313" Gaslift Mandrel,Camco MM,Port 12 7 8,422' 2.867" 5.313" Gaslift Mandrel,Camco MM,Port 16 8 9,041' 2.867" 5.313" Gaslift Mandrel,Camco MM,Port 16 11 I I I� 9 9,628' 2.867" 5.313" Gaslift Mandrel,Camco MM,Port 16 12 I :i Id 10 10,184' 2.867" 5.313" Gaslift Mandrel,Camco MM,Port 16 I111 10,709' 2.867" 5.313' Gas Lift Orifice,Port Size 20 13 3 E 31 3E " 12 10,735' 2.813" 5.91" On/Off Tool,w/X-Nipple M _ _ 13 10,774' 3" 5.875" Packer Arrowset AS1-X Mech. 14 10,779' 2.813" 3.52" X Nipple 14 - 15 10,791' 3" 4.5" WLEG _ WSO 16 11,077' - Cement Retainer,Capped w/10 sx cement 15 H-4 Perforation History . - H_5 Zone Top(MD) Btm(MD) Top(MD) Btm(MD) Amt spf Comments 12/11/58 WSO 10,795' 10,796' 10,795' 10,796' 1' 4 - WSO 12/14/58 H-4 10,804' 10,836' 10,804' 10,836' 32' 4 - H-6 12/14/58 H-5 10,849' 10,878' 10,849' 10,878' 29' 4 12/11/58 WSO 10,880' 10,881' 10,880' 10,881' 1' 4 H-7 Milled K 8/31/2012 H-6 10,906' 10,916' 10,906' 10,916' 10' 6 2.5"Owen retainer ' to H-10 8/31/2012 H-7 10,926' 10,948' 10,926' 10,948' 22' 6 2.5"Owen 11,077' Hemlock 12/09/58 Hemlock 11,038' 11,060' 11,038' 11,060' 22' 4 Open 16 i 8/31/2012 H-10 11,050' 11,076' 11,050' 11,076' 26' 6 2.5"Owen - - 12/07/58 Hemlock 11,185' 11,195' 11,185' 11,195' 10' 4 Isolated 7" _ -Hemlock 11,620' iT r: TD=12,046' PBTD=11,077' Downhole Proposed Updated by STP 07/31/13 RECEIVED STATE OF ALASKA . ALAQA OIL AND GAS CONSERVATION COMMON JUL 19 2013 REPORT OF SUNDRY WELL OPERATIONS AOGCC 1.Operations Abandon U Repair Well U Plug Perforations U Perforate U Other [✓j Convert to ESP Performed: Alter Casing ❑ Pull Tubing es Stimulate-Frac ❑ Waiver ❑ Time Extension❑ Change Approved Program ❑ Operat.Shutdown❑ Stimulate-Other ❑ Re-enter Suspended We0❑ 2.Operator 4.Well Class Before Work: 5.Permit to Drill Number: Name: Hilcorp Alaska,LLC Development 11511 Exploratory ❑ 100-148 3.Address: 3800 Centerpoint Drive,Suite 100,Anchorage, Stratigraphic❑ Service ❑ 6.API Number: Alaska 99503 50-133-10156-00 7.Property Designation(Lease Number): 8.Well Name and Number: FEDA028406 Swanson River Unit(SRU)331-27 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): N/A Swanson River Field/Hemlock Oil 11.Present Well Condition Summary: Total Depth measured 12,046 feet Plugs measured 11,077 feet true vertical 12,046 feet Junk measured N/A feet Effective Depth measured 11,077 feet Packer measured N/A feet true vertical 11,077 feet true vertical N/A feet Casing Length Size MD TVD Burst Collapse Structural Conductor 22' 20" 22' 22' Surface 1,490' 13-3/8" 1,490' 1,490' 2,730 psi 853 psi Intermediate Production 11,620' 7" 11,620' 11,620' 604 psi 7,240 psi Liner Perforation depth Measured depth See Attached Schematic �1 True Vertical depth See Attached Schematic SCANNED NOV 0 6 2013 Tubing(size,grade,measured and true vertical depth) 3-1/2" L-80 10,750'MD 10,750'TVD Packers and SSSV(type,measured and true vertical depth) N/A N/A N/A N/A 12.Stimulation or cement squeeze summary: N/A Intervals treated(measured): N/A Treatment descriptions including volumes used and final pressure: N/A 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 167 136 475 1,050 210 Subsequent to operation: 0 0 0 0 0 14.Attachments: 15.Well Class after work: Copies of Logs and Surveys Run N/A Exploratory❑ Development El Service ❑ Stratigraphic ❑ Daily Report of Well Operations X 16.Well Status after work: Oil 0 Gas ❑ WDSPI❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP❑ SPLUCO 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: 313-321 Contact Stan Porhola Printed Name Stan Porhola Title Operations Engineer Signature ,/� • t Phone 907-777-8412 Date 11-2-71--2 3 7•Z 13 RBDMS JUL 2 4 2013A Form 10-404 Revised 11/2011 �/0 Submit Original Only • . Hilcorp Alaska, LLC Well Operations Summary Well Name API Number Well Permit Number Start Date End Date SRU 331-27 50-133-10156-00 100-148 7/9/13 7/13/13 Daily Operations: 07/09/2013 -Tuesday Laid containment and spotted WORE. MIRU SL, RIH 2.85" GR to 10,744' wlm. POOH. RIH w/PX plug and set in X-nipple (on/off tool) at 10,744'. POOH. RIH w/PX prong and set in plug at 10,742' wlm. POOH. RIH w/kick over tool and found bottom gaslift valve at 10,709'wlm. Sheared off tool. POOH. RIH w/kick over tool to 10,709'wlm. Latched GLV and POOH. ' RDMO SL. Secured well and SDFN. 07/10/2013 -Wednesday Finished RU and removed flow/GL lines. Filled well with PW and broke cirulation. Circulated 280 bbls and tested csg to 1,500psi (charted for 30 mins). Installed a TWC in tbg hanger. ND PT, NU BOP Stack. Tested BOPE,Annular 250-1500psi, Values/Rams 250-3,000psi. (Witness waived by Jim Regg,AOGCC.) Charted each test for 10 mins. Pulled TWC. MIRU SL, RIH w/2.5"JDC to 10,756', POOH w/prong. RIH w/3.5"GS to 10,761', POOH w/PX plug. RDMO SL. Prepped the rig to pull pipe. Pulled tbg hanger and released packer. LD tbg hanger. TOOH w/35 stands of 3-1/2" 9.3# EUE TBG and one GLM. Secured well and SDFN. 07/11/2013 -Thursday TOOH w/131 stands, 1 single of 3-1/2" 9.3# EUE 8RD tbg. 10 glm, packer, X-nipple and WLRG. PU ESP BHA, 2'x 4.56" centralizer, 1.90'x 4.50" base gauge, 31.30' x 4.56" motor, 31.60'x 4.56" motor, 8'x 4" protector, 8' x 4" protector, 3.30' x 4" intake, 6.60' x 4" AGH, 22' x 4" pump, 22'x 4" pump, 22'x4 " pump, 22'x 4" pump, .75" x 4.63" discharge pressure sub assy and .80' x 4" head. TIH w/66 stands of 3-1/2" EUE 9.3#8RD tbg. Note: Installed 18 cannon 4560 clamps and 8 cannon 4560 ' clamps for power cable/control line on ESP. Installed 9-3/4" bands on first jnt of 3-1/2" tbg. Installed 3 bands for power cable ever joint and 1 band ever other joint for control line. 07/12/2013 - Friday Continued RIH w/ESP and 106 stands of 3-1/2" EUE 9.3#8RD tbg, ESP power cable and dual-pack control line. Put 3 band per joint on power cable and 1 band ever other joint of control lines. Note: Made a power cable splice at 6,500'. 07/13/2013-Saturday Made Surface splice for ESP power cable connection+A16. Made up tbg hanger, ran dual-pack .25" control line and power cable thru hanger. Landed hanger and tested. Installed BPV, ND BOP stack. Tested the control lines an NU production tree. Pulled BPV and secured well. SDFN. • • • Soldotna Creek Unit • Well: SRU 331-27 ACTUAL SCHEMATIC Completion Ran:7/13/2013 PTD:100-148 Hilcorp Alaska,LLC API: 50-133-10156-00 RKB:272'/GL:257'AMSL Casing Detail KB-THF:15.0' Size Type Wt Grade ID Top Btm Hole Cmt Cmt Top 1 20" Conductor - Surf 22' unknown Surf. 20" a. ,,�, 18-%" 22' 13-%" Surface 54.5 1-55 12.615" Surf 1,490' 1,500 sx Surf. 1,497' 12 '/<„ r4 7" 29 P-110 6.184" Surf 1,027' 2 725 wee' 13-3/8" '"' 7" 29 N-80 6.184" 1,027' 2,172' 10-3/4" 1,490' Prod Csg 11,659' 1,000 sx 9,140'CBL 7" 26 N-80 6.276" 2,172' 8,192' 7" 29 N-80 6.184" 8,192' 10,695' 7" 29 P-110 6.184" 10,695' 11,620' Tubing Detail Cplg OD 3.5" EUE 8RD 9.3 L-80 2.992" Surface 10,750' T"ks"",``. K 4.500" Jewelry Detail No. Depth ID OD Item 1 17' 2.992" 6.184" Tubing Hanger w/IBT x 8rd EUE XO 2 10,750' - 4.560" ESP,456 series Motors/400 series Pumps 3 11,077' - - Cement Retainer,Capped w/10 sx cement CBLTOC 9,140' r 1 . Ii 1 7:3(14,-. i Ig .W 2 s wsO H-4 -" Perforation History H-5 Date Zone Top(MD) Btm(MD) Top(MD) Btm(MD) Amt spf Comments 12/11/58 WSO 10,795' 10,796' 10,795' 10,796' 1' 4 WSO 12/14/58 H-4 10,804' 10,836' 10,804' 10,836' 32' 4 Squeezed .r ' H-6 12/14/58 H-5 10,849' 10,878' 10,849' 10,878' 29' 4 Squeezed ` r H-7 12/11/58 WSO 10,880' 10,881' 10,880' 10,881' 1' 4 Milled K 8/31/2012 H-6 10,906' 10,916' 10,906' 10,916' 10' 6 2.5"Owen retainer 'tri '` to H-10 8/31/2012 H-7 10,926' 10,948' 10,926' 10,948' 22' 6 2.5"Owen 11,077' Hemlock 12/09/58 Hemlock 11,038' 11,060' 11,038' 11,060' 22' 4 Open 4,4 - ' i ,,. 8/31/2012 H-10 11,050' 11,076' 11,050' 11,076' 26' 6 2.5"Owen ►1" + 12/07/58 Hemlock 11,185' 11,195' 11,185' 11,195' 10' 4 Isolated 7„ .21S-_Hemlock 11,620' A► °,,a.. f-V'r TD=12,046' PBTD=11,077' Downhole Revised:7/13/2013 Revised By STP 7/19/2013 • • ti of Tit 0 I % %is THE STATE Alaska Oil and Gas ALASKA Conservation CommISSI ®11 A GOVERNOR SEAN PARNELL 333 West Seventh Avenue Anchorage, Alaska 99501 -3572 � F ALA`�� P 9 Main: 907.279.1433 Fax: 907.276.7542 Stan Porhola SCANNED JUL 0 3 Z013. Operations Engineer Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 100 Anchorage, AK 99503 Re: Swanson River Field, Hemlock Oil Pool, SRU 331 -27 Sundry Number: 313 -321 Dear Mr. Porhola: 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. Sinc el , 4 orm. issioner DATED this /day of July, 2013. Encl. ,!C3• ›\) ` � STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS -, ... 20 AAC 25.280 1. Type of Request: Abandon ❑ Plug for Redril ❑ Perforate New Pod ❑ Repair Wdl❑ Change Approved Program ❑ Suspend ❑ Plug Perforations ❑ Perforate ❑ PuN Tubing El • Time Extension ❑ Operations Shutdowl ❑ Re -enter Susp. Wel ❑ Stimulate ❑ Alter Casing❑ 'Other. Convert to ESP 151 • 2. Operator Name: r. Hilcorp Alaska, LLC 4. Current Well Class: 5. Permit to Drill Number Exploratory ❑ Development s • 100-148 • 3. Address: 3800 Centerpoint Drive, Suite 100 Stratigraphic ❑ Service ❑ 6. API Number. • Anchorage, Alaska 99503 50-133-10156-00 7. If perforating: 8. Wep Name and Number. What Regulation or Conservation Order governs well spacing in this pool? N/A Swanson River Unit (SRU) 331 -27 • Will planned perforations require a spacing exception? Yes ❑ No El 9. Property Designation (Lease Number): 10. Field /Pool(s): FEDA028406 Swanson River Field / Hemlock Od 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): 12,046 • 12,046 • 11,077 11,077 11,077' N/A Casing Length Size MD TVD Burst Collapse Structural Conductor 22' 20" 22' 22' Surface 1,490' 13 -3/8" 1,490' 1.49(7 2,730 psi 853 psi Intermediate Production 11,620' 7" 11,620' 11,620' 605 psi 7,240 psi Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): See Attached Schematic See Attached Schematic 3 -1/2" 9.3# /1-80 10,791' Packers and SSSV Type: Packers and SSSV MD (t) and TVD (ft): Arrowset AS1 -X Mech; N/A 10,784' MD - 10,784' TVD; N/A 12. Attachments: Description Summary of Proposal El 13. Well Class after prop•sed work: Detailed Operations Program n BOP Sketch n Exploratory n Stratigraphin Development [ ] Service n 14. Estimated Date for 15. Well Status after prop sed work: 07/05/13 Commencing Operations: Oil Q 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 Stan Porhola Phone: 907- 777 -8412 Email sDorhola( hilcora.com Printed Name .4 SA Stan Por ola Title Operations Engineer Signature . GG; �`�b Phone 907 - 777 -8412 Date V9--c 3 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 313 ,3 , ) Plug Integrity ❑ BOP Test Ll�l Mechanical Integrity Test ❑ Location Clearance ❑ �� Other: 4e.-30aD r . 4 0e •�5' . - r) s � if /0 -'� -��`' tom" it .5 iv I �:(' 1 --4 -3 1— 'I JJ \\ e c5i - .-- .-, / 5 - da /3,- . RBDMS JUL -3 2O ■ Spacing Exception Required? Yes ❑ No R� • sequent Form Required: /a ya`/ APPROVED BY Approved by: Olt COMMISSIONER THE COMMISSION Date: 0745 111( Submit 4_ G•l6 ./3 Submit Form and 1) Form 10-403 (Revised 10/2012) Appr�v) V ci p cGrlil l�itk rllz months from the dat approval. Attachments i �k k� VV ` III��� / l/ l7 • • Well Prognosis • Well: SRU 331 -27 Hilcorp Alaska, LLB Date: 6/20/2013 Well Name: SRU 331 -27 API Number: 50- 133 - 10156 -00 Current Status: Producing Oil Well Leg: N/A Estimated Start Date: July 5, 2013 Rig: Williams #405 Reg. Approval Req'd? 403 Date Reg. Approval Rec'vd: Regulatory Contact: Donna Ambruz 777 -8305 Permit to Drill Number: 100 -148 First Call Engineer: Stan Porhola (907) 777 -8405 (0) (907) 229 -4824 (M) Second Call Engineer: Chad Helgeson (907) 777 -8405 (0) (907) 229 -4824 (M) AFE Number: 1321774 Current Bottom Hole Pressure: — 3,117 psi @ 10,841' TVD (Static survey April 2012 mid perf of 10,841' MD) Maximum Expected BHP: — 3,117 psi @ 10,841' TVD (Static survey April 2012 mid perf of 10,841' MD) Max. Allowable Surface Pressure: —0 psi (Based on actual reservoir conditions and min water cut of 50% (0.385psi /ft) will balance reservoir pressure at 2,745 ft. TVD. Brief Well Summary This well was drilled and completed as an oil well in Hemlock benches H -4, H -5, & H -10 in 1958. A workover performed in 1963 isolated the H -10 and reperforate the H -4 & H -5 zones. A workover in 1971 converted the well to gas injection. Gas injection was halted in 1981 and the well remained shut in until 2012. A workover performed in 2012 was performed to pull tubing and packers, cement squeeze the H -4 and H -5, pressure test casing, drill out cement, pressure test squeeze, cleanout fill, BPs, perforate H -6, H -7, and H -10 and ran a GL completion. The plannedhrQrkov r will. • ulI he existin: corn .letion and convey the w- II from "a_GL com In etion_ to_ESP comjIetion. Notes Regarding Wellbore Condition • Current well status is gas lifted oil producer. Work -Over Rig Procedure e tee," as 1. MIRU Williams 405 pulling unit. c'rot_ ! < lc- sI-C- 2. Install back pressure valve in tbg hanger. Note: If hanger profile is not test worthy, call out slick line with tubing stop /plug and set at 500'. 3. Set BPV in tubing hanger, ND tree, NU 7- 1/16" BOPE and test to 250psi low /3,000psi high, annular to 250psi low /1,500psi high (hold each valve and test for 10 -min). Record accumulator pre- charge pressures. a. Notify AOGCC 24hrs in advance to witness test. b. Notify BLM 48 hrs in advance of BOP test. c. Crew will be working 12hr shifts and well will be secured nightly with TIW valves and BOPE. 4. Release test pressure, pull tubing stop or BPV and install handling sub in hanger. 5. Back out tbg hanger hold down pins and pick up on hanger. • • 14 Well Prognosis Well: SRU 331 -27 Hilcorp Alaska, ice Date: 6/20/2013 6. RU to pull tubing hanger and unseat Arrowset AS1 -X packer at 10,784' (right -hand release) and SOOH with 3 -1/2" production tubing down to 10,791'. Jar tubing hanger and packer loose if necessary. a. If unable to unseat packer, attempt to release from the On /Off Tool at 10,745'. b. If unable to unseat packer or On /Off Tool, RIH with E -line and use radial cutting torch to cut 3 -1/2" tubing at +/- 10,730'. c. SOOH with tubing and RIH with overshot and jars and pull AS1 -X packer. 7. RIH with ESP with existing 3 -1/2" 8rd EUE L -80 tubing. Set ESP at +/- 10,750'. Land tubing hanger. 8. Set BPV, ND BOPs, NU Tree, test tree to 3,000 psi. a. Note: Rated pressure of BIW penetrator (wellhead to cable connection) is 3,000 psi. 9. RDMO workover rig and equipment. 10. Turn well over to production. (Notify BLM after 5 days of Production). 11. Notify AOGCC to conduct a no flow test on t_ he well.after it has flowed for 5 days at a stable production. `y` '— Attachments: 1. As -built Schematic 2. As -built Wellhead 3. Proposed Schematic 4. Proposed Wellhead 5. BOP Schematic II • • Swanson River Unit SCHEMATIC well: SRU 331 -27 Completion: 8/27/2012 Hilcorp Alaska, LLC PTD# 100 -148 RKB: 272' / GL: 257' AMSL KB- THF:15.0' Casing Detail Size Type Wt Grade ID Top Btm Hole Cmt Cmt Top 20 " n 1 20" Conductor - - - Surf 22' - unknown Surf. „ 22' 13 %" Surface 54.5 J-55 12.615 Surf 1,490' 18-% 1,500 sx Surf. 1,497' 7" 29 P -110 6.184 Surf 1,027' 12 ° ' ..i 21c7Z ,725' 13 -3/8" .� Z' 7" 29 N -80 6.184 1,027' 2,172' 1,490 2 ■ Prod Csg 11,659' 1,000 sx 9,140' CBL II I 7" 26 N-80 6.276 2,172' 8,192' 3 ; MI ' 7" 29 N -80 6.184 8,192' 10,695' 7" 29 P -110 6.184 10,695' 11,620' 4 1.111 ' Tubing Detail CpIgOD I I I 3.5" 9.3 L80 2.992 Surface 10,791' ' "' A 4.53" 5 MO i Jewelry Detail 6 No. Depth ID OD Item E EXO 1 17 2.992" 7" Tubing Hanger w/ IBT x 8rd U 7 1=11 i III 2 2,296' 2.867" 5.313" Gaslift Mandrel, Camco MM, Port 12 8 MID ; 3 4,223' 2.867" 5.313" Gaslift Mandrel, Camco MM, Port 12 CBLTOC III 4 5,827' 2.867" 5.313" Gaslift Mandrel, Camco MM, Port 12 9,140 9 INK i 4, 5 7,021' 2.867" 5.313" Gaslift Mandrel, Camco MM, Port 12 imi V 10 a 6 7,833' 2.867" 5.313" Gaslift Mandrel, Camco MM, Port 12 7 8,422' 2.867" 5.313" Gaslift Mandrel, Camco MM, Port 16 11 -- 8 9,041' 2.867" 5.313" Gaslift Mandrel, Camco MM, Port 16 9 9,628' 2.867" 5.313" Gaslift Mandrel, Camco MM, Port 16 12 ",,l,. 10 10,184' 2.867" 5.313' Gaslift Mandrel, Camco MM, Port 16 are ►+" 11 10,709' 2.867" 5.313" Gas Lift Orifice, Port Size 20 13 t . l 1 1 12 10,745' 2.813" 5.91" On/ Off Tool, w/ X- Nipple - # - I l 13 10,784' 3" 5.875" Packer Arrowset AS1 -X Mech. 4 «.+ tr 14 10,789' 2.813" 3.52" X Nipple, (Do not try to set PX plug in this nipple) 14 I, Ilk s i WSO 15 10,791' 3" 4.5" WLEG qii I P 16 11,077' - - Cement Retainer, Capped w/ 10 sx cement _. 15 r- ,1 + H -4 ,' Perforation History i %. H_s Date Zone Top(MD) Btm(MD) Top(MD) Btm(MD) Amt spf Comments * 12/11/58 WSO 10,795' 10,796' 10,795' 10,796' 1' 4 ' WSO 12/14/58 H -4 10,804' 10,836' 10,804' 10,836' 32' 4 I ts H - 12/14/58 H -5 10,849' 10,878' 10,849' 10,878' 29' 4 tf`l ` H -7 12/11/58 WSO 10,880' 10,881' 10,880' 10,881' 1' 4 Milled K 8/31/2012 H -6 10,906' 10,916' 10,906' 10,916' 10' 6 2.5" Owen retainer ,2 t' *j to H -10 8/31/2012 H -7 10,926' 10,948' 10,926' 10,948' 22' 6 2.5" Owen 11,077' , .... 41751.. Hemlock 12/09/58 Hemlock 11,038' 11,060' 11,038' 11,060' 22' 4 Open 16 V- ,t' - ,r , ' *. " ` ' 8/31/2012 H -10 11,050' 11,076' 11,050' 11,076' 26' 6 2.5" Owen _ 12/07/58 Hemlock 11,185' 11,195' 11,185' 11,195' 10' 4 Isolated 7 „ 3 1= Hemlock 11,620' 4 . g,,• ;' TD = 12,046' PBTD = 11,077' Revised By TDF 10/2/2012 - • • Swanson River Unit , PROPOSED SCHEMATIC Well: SRU 331 -27 Proposed Hilcorp Alaska, LLC PTD# 100 -148 RKB: 272' / GL: 257' AMSL KB- THF:15.0' Casing Detail Size Type Wt Grade ID Top Btm Hole Cmt Cmt Top M` 1 vi---t F ' 4 20" Conductor - - - Surf 22' - unknown Surf. 20 " gx$ 22' 18 -% 13-%" Surface 54.5 J -55 12.615" Surf 1,490' 1 497 1,500 sx Surf. . ' 7" 29 P -110 6.184 Surf 1,027' 12-1 2' EL: 5 13 -3/8" w 7" 29 N -80 6.184 1,027' 2,172' 10 -% 1,490' Prod Csg 11,659' 1,000 sx 9,140' CBL 7" 26 N -80 6.276 2,172' 8,192' 7" 29 N -80 6.184 8,192' 10,695' 7" 29 P -110 6.184 10,695' 11,620' Tubing Detail Cplg OD 3.5" EUE 8RD 9.3 L -80 2.992 Surface 10,791' f # . 4.500" Jewelry Detail No. Depth ID OD Item ' 1 17 2.992" 7.000" Tubing Hanger w/ IBT x 8rd EUE XO 2 10,750' - 4.560" ESP, 456 series Motors / 400 & 387 series Pumps 3 11,077' - - Cement Retainer, Capped w/ 10 sx cement CBLTOC 9,140' .;� i,,, 7 " ttOit '...,: 0< 2 1: 4 ` Perforation History H -5 Date Zone Top(MD) Btm(MD) Top(MD) Btm(MD) Amt spf Comments �� 12/11/58 MO 10,795' 10,796' 10,795' 10,796' 1' 4 ,, # WSO . 12/14/58 H -4 10,804' 10,836' 10,804' 10,836' 32' 4 Squeezed H -6 12/14/58 H -5 10,849' 10,878' 10,849' 10,878' 29' 4 Squeezed g s 12/11/58 WSO 10,880' 10,881' 10,880' 10,881' 1' 4 it Milled K H -7 8/31/2012 H -6 10,906' 10,916' 10,906' 10,916' 10' 6 2.5" Owen retainer t' to # H -10 8/31/2012 H -7 10,926' 10,948' 10,926' 10,948' 22' 6 2.5" Owen 11,077' ,, %k. Hemlock 12/09/58 Hemlock 11,038' 11,060' 11,038' 11,060' 22' 4 Open 3 y,.' i r ` *.,' 8/31/2012 H-10 11,050' 11,076' 11,050' 11,076' 26' 6 2.5" Owen i 21 . _A Hemlock 12/07/58 Hemlock 11,185' 11,195' 11,185' 11,195' 10' 4 Isolated , 7 " i 11,620' : -0 .z =' K: : TD = 12,046' PBTD = 11,077' Revised By STP 6/20/2013 • • Swanson River CURRENT WELLHEAD SRU331 -27 11,1...q. u.:.).:. 11 ■ 05/20/2013 Tubing hanger, Seaboard - SRU 331 -27 S -EN -CCL, 7 X 3'/2 EUE 133/8X7X3'A lift X3% Hydril563susp, w/ 3" Type H BPV, 3/8 CCL, 4 5/8 EN BHTA, Bowen, 3 1/8 5M FE X 3" Bowen top O . u: u: �0 �0 Valve, swab, WKM -M, S1 ` c � < \ < � 3 1/8 5M FE, HWO, DD �.� a dz, h1\ `.\ ' s h �e trim y �� Ja Aq Valve, Wing, WKM M . A , - i N / _ A - 2 1/16 5M FE, HWO, iikiil 4 4 :P 1 (. ll DD trim , o i Valve, master, WKM -M, p A 3 1/8 5M FE, HWO, DD :" trim ° ::: — Valve, master, WKM -M, $ 3 1/8 5M FE, HWO, DD {J. trim .1 IminAll Adapter, Seaboard -EN -CCL, 7 1/16 5M Stdd btm X MI- 3 1/8 5M stdd top, Tubing head Attachment, ,...m•-1111M1 i'�� !'._ Seaboard S -8, 9' 5M FE X NI 111 7 1/16 5M FE lei 1II1 Tubing head, Regan - 11= i.= Double screwlock, 12" III series 1500 R -58 bottom � Valve, McEvoy -C, 2 1/16 5M (ANSI series) X 9" SM FE OA ' _ ���� 2- 2 1/16 SM EFO ;�1��- l I1f �i�: �' PN: 14572 -C4 i j _ II Casing head, Shaffer KD 12" series 1500 R -58 FE top X 13 �� ... MI 3/8 SOW bottom, w/ 2- 2 1/ / 3 ` � 16 SM EFO i ■ ' I IlI!P CT'■ Valve, WKM -M, 2" LPO Valve, plug, 2" LPO Or • • Swanson River PROPOSED WELLHEAD SRU331 -27 05/20/2013 11,1.-..,,, ‘L,.ka.1.1 SRU 331 -27 Tubing hanger, Seaboard - 133/8X7X3'''A S -ESP, 7X3'/ BTC lift and susp, w/ 2 -% control line exits, prepped for BIW Kwiklok penetrator BHTA, Bowen, 3 1/8 5M FE X 3" Bowen top . .i, A .4. 4.P V�� O IN Valve, swab, WKM -M, "' S l` 4',' � o � 'Z � 3 1/8 5M FE, HWO, DD I '! `1t J a �e Q>4, '6 � 9' � , ,s t c trim � N. -.V i 3 Valve, Wing, WKM -M, \ / - S _ lip 2 10•4411 110•All V 1/16 5M FE HWO DD trim Valve, master, WKM -M, . „ `, 3 1/8 5M FE, HWO, DD trim VOW " s „ ice" „ p � Valve, master, WKM -M, 31 /85MFE,HWO,DD 3. <4" trim 'ZIC- ,., nil III 1 Adapter, Seaboard -ESP, ` 1 — 7 1/16 5M Rotating Flange X IsI 1 1.-- ra � t I 3 1/8 5M Rotating Flange, 11 .1, i i -j � w/ 2- 4 CCI, BIW penetrator Tubing head Attachment, , , Seaboard S -8, 9" 5M FE X =.171 � �: L limisarol r• -- 7 1/16 5M FE 111 Ill 1 esi ui ili I psi L I , Tubing head, Regan- :a= =10 Double screwlock, 12" NI = 111 series 1500 R -58 bottom ,, McEvoy -C, 2 1/16 5M (ANSI series) X 9" 5M FE I'iiI qt 111 i "� `I� I i Qty 2 2- 2 1/16 5M EFO _ PN : 14572 -C4 111,_. . III miff � - _ Casing head, Shaffer KD 12" al series 1500 R -58 FE top X 13 ICI 7 1 1 1 3/8 SOW bottom, w/ 2- 2 1/ _ 165M ., 1� 1. nu is1 • -, 1 ` t]M :� ; _ � V�� Valve, WKM -M, 2" LPO Valve, plug, 2" LPO ill ; 1 • • Swanson River 2013 Williams Rig 405 Hilrarp : \ist�kn, l.l.f Knight Oil Tools BOP f 1 0 0 til di ill It Ill Ii, 1i1 1i1 2.57' Shaffer 71/16 5000 I11, I11 111 111 111 111 1!11!1 1!I 2 3/8 -3 A variable CAMERON 3.68' 1 it' ll Vo ` I� o Mgt F. =Earl Blind _ ■01 7 1/16 5000 I ®o 1 1 Choke and Kill valves are 2 1/16 10M rOcj 111 1 #i 1!1.111 111 1.56' i Ael '• 7 1/16 5000 ; - III 1N1 , Lin STATE OF ALASKA AL. OIL AND GAS CONSERVATION COMMMION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon U Repair Well U Plug Perforations U Perforate o Other U Injector to Producer ' Performed: Alter Casing ❑ Pull Tubing 1151 Stimulate - Frac ❑ Waiver ❑ Time Extension ❑ O i Re -enter Suspended Well Change Approved Program ❑ pest. Shutdowr ❑ Stimulate Other ❑ p ❑ • 2. Operator 4. Well Class Before Work: 5. Permit to Drill Number: Name: Hilcorp Alaska, LLC Development ❑ Exploratory ❑ — 100 -148 3. Address: 3800 Centerpoint Drive, Suite 100, Anchorage, Stratigraphic ❑ Service 1151 6. API Number: Alaska 99503 50- 133 - 10156 -00 " 00 7. Property Designation (Lease Number): 8. Well Name and Number: FEDA028406 Swanson River Unit (SRU) 331 -27 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field /Pool(s): N/A Swanson River Field / Hemlock Oil 11. Present Well Condition Summary: Total Depth measured 12,046 feet Plugs measured 11,077 feet true vertical 12,046 feet Junk measured N/A feet Effective Depth measured 11,077 feet Packer measured 10,784 feet true vertical 11,077 feet true vertical 10,784 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 22' 20" 22' 22' Surface 1,490' 13 -3/8" 1,490' 1,490' 2,730 psi 853 psi Intermediate Production 11,620' 7" 11,620' 11,620' 604 si 7,240 psi Liner RECEIVED Perforation depth Measured depth See Attached Schematic OCT 0 2 2012 True Vertical depth See Attached Schematic AC'S G C1�M// �°a Tubing (size, grade, measured and true vertical depth) 3 -1/2" L -80 10,791' MD 10,791' TVD Arrowset Packers and SSSV (type, measured and true vertical depth) AS1 -X Mech N/A 10,784' MD 10,784' TVD 12. Stimulation or cement squeeze summary: N/A Intervals treated (measured): N/A SCANNED JAN 2 3 2013 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 1,450 1,000 Subsequent to operation: 500 150 50 1,050 225 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run N/A Exploratory ❑ Development IN • Service ❑ Stratigraphic ❑ Daily Report of Well Operations X 16. Well Status after work: Oil — 0 Gas ❑ WDSPI❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP ❑ SPLUcD 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 -272 Contact Chad Helgeson Phone: 907 - 777 -8300 Printed Name Chad Helgeson Title Operations Engineer Signature 1/f/I4 Phone 907-777 -8405 Date / p , z_ i8 OMS OCT 0 3 2012 V I- P � �1 1 Form 10-404 Revised 11/2011 Submit Original Only • • Hilcorp Alaska, LLC Well Operations Summary Y Well Name API Number Well Permit Number Start Date End Date SRU 331 -27 50- 133 - 10156 -00 100 -148 7/28/12 8/31/12 Daily Operations: 7/28/2012 - Saturday HSM, MI started. RU WOR and equipment. 7/29/2012 - Sunday Continue RU up WOR and equipment. Loaded rig tank with produced saltwater. MIRU Pollard E -line Unit, Made 2 runs, logged and Radial torch cut in 2 places. First cut @ 10,833 and second cut @ 10,762. RDMO Pollard Unit. 7/30/2012 - Monday Checked Pressure on well, Zero psi on well. RU pump and pumped 165 Bbls of produced saltwater. Got no returns. Set back pressure valve in tbg hanger. ND well -head. NU BOP's. Continue RU WO equipment. Prepare for BOP test with Lou Grimaldi, AOGCC @ 8 am wed morning. 08/01/2012 - Wednesday Finished RU WOR and Equipment. Pumped 100 bbls of produced SW down tbg. Shot fluid level again after 3 hrs, FL @ 3,193'. Shot 2nd fluid level 6 hrs after pumping, FL @ 3,618'. Cameron wellhead hands pulled lock pins on tbg head. PU 1 jt of 3.5 tbg. Screwed into top of tbg hanger. PU to 120,000 on weight indicator. POOH w/ tbg hanger. Pulled and LD 2 more jts of 3.5" prod string. Secured Well, SDFN. 08/02/2012 - Thursday Continued LD 3.5" production string. LD 353 jts of 3.5 ", X -over and 1 jt of 2 -7/8" PS, 1 GLM, and half joint of 2 -7/8 ". Pump fluid after every 10 jts to ensure fluid level. Secured Well, SDFN. 08/03/2012 - Friday Loaded 353 Jts of 3.5" PS onto pipe trailers. Unloaded & tallied 2 -7/8" P110 work string. MU overshot loaded with 2 -7/8" grapple, 1 bumper jar, 6 drill collars, 1 accelerator jar, and cross -over to 2 -7/8" P110. Secured well, SDFN. 08/04/2012 - Saturday Started TIH w/ 2 -7/8" P110 WS. TIH w/ 335 jts of WS. Tagged up on fill @ 10,663'. Left EOT @ 10,648'. SD, Secured Well, SDFN. 08/05/2012 - Sunday PU power swivel. Swiveled & washed down 4 jts of 2 -7/8" P110 WS. Engaged packer @ 10,762'. Pulled 35,000 over string weight. Released Baker Model FH packer. POOH w/ 2 -7/8" WS. LD packer and tail pipe. Secured Well, SDFN. 08/06/2012 - Monday Mixed 15 bbl salt pill with Baroid Hand. Pumped down 7" casing. Chased down with total of 168 bbls of produced SW. Welbore pressured up to ,2800 psi. SD pumps. MU burn shoe on 1 jt of wash pipe, bumper jar, 6 drill collars, accelerator jar and 169 stands of 2 -7/8" P110 WS. Pumped 13 bbls of produced SW and started getting returns. SD, Secured Well, SDFN. 08/08/2012 - Wednesday Tested BOPs (250 psi low - 3,000 psi high, witness waived by Jim Regg, AOGCC) and all surface valves. MU overshot loaded with 2 -7/8" grapple. TIH w/ overshot, 1 bumper jar, 6 drill collars, 2nd bumper jar and 93 stands of 2 -7/8" WS. EOT @ 6,003'. Secured well. SDFN. • • 08/092012 - Thursday Continued TIH to top of ish. Engaged overshot /grapple on 2 -7/8" tbg fish. POOH. LD tbg, seal assembly and tbg tail pipe. Packer pulled off of seals. 08/10/2012 - Friday MU 4' X 2 -3/8" OD spear. TIH w/ spear, bumper jar, 6 drill collars, accelerator jar, and 171 stands of 2 -7/8" P110 WS. Speared into top of packer. PU and immediately started dragging. PU to 120,000 on weight indicator at each collar for first 11 stands. Had of beat through next 2 collars. Continued out of hole slowly. Packer continued to drag for first 43 stands. POOH w/ 140 stands. EOT at 2,137'. Secured well, SDFN. 08/11/2012 - Saturday Continue POOH w/ 2 -7/8" WS with spear and packer. LD packer and spear. MU 7" X 3 -1/2" Arrow RTTS packer. TIH to 3,500'. Set packer and tested casing to 1,500 psi. Unset packer and TIH to 4,000'. Set and tested casing to 1,500 psi. Unset packer and TIH to 4,000'. Set and tested casing to 1,500 psi. Unset packer and TIH to 4,500'. Set packer and tested casing to 1,500 psi. Unset packer and TIH to 5,000'. Set packer and tested casing to 1,500 psi. Unset packer and TIH to 5,500'. Set 08/12/2012 - Sunday " Packer. w/ 172 stands of 2 -7 8 P110 WS. POOH w/ 6 drill collars and BHA. LD Haliburton RTTS Pac r. MU 4 blade cement e junk mill on 2 boot baskets, bumper jar, 6 drill collars, and TIH w/ 10 stands of 2 -7/8" P110 WS. Secured well, SDFN. 08/13/2012 - Monday Continue TIH w/ 6.03 Cement junk mill. Tagged fill and cement @ 10,878'. Drilled down to 10,975' and tagged bridge plug. Mixed 15 bbl high visc sweep. Circulated bottoms up. Secured well. SDFN. 08/15/2012 - Wednesday Finish POOH, Test BOPs (250 psi low - 3,000 psi high). Witness waived by Jim Regg, AOGCC. 08/17/2012 - Friday TIH with 172 stands of 2 -7/8" P110 workstring. Milling on bottom plug. Made 1 ft on plug, circulated hole with 320 Bbls of 200 degree hot 9.3 brine water. POOH w/ 1 stand. Secured well, SDFN. 08/18/2012 - Saturday Milled bottom plug to 11,077'. Circulate 20 bbl sweep around. Lost 63 bbls total during milling yesterday, took 24 bbls to fill hole. POOH with 2 -7/8" workstring and mill. Broke out BHA and mill. Mill had approximately 40% wear, will be rerunning it on the casing scraper run. 08/19/2012- Sunday Go in hole with mill and casing scraper to 11,070'. Mixed and pumped sweep around, circulate well clean. 08/20/2012 - Monday Pull 3 stands, PU X -overs and Halliburton RTTS. RIH w/ 1 stand and set too. Back out of tool and POOH. Nipple down Hydril and set back. Nipple down BOPs from well head and PU. Remove DSA. Install spoo. NU. Test BOP breaks. 08/21/2012 - Tuesday Pump sweep around, POOH and lay down 2 -7/8" workstring 08/22/2012 - Wednesday Finished running 3 -1/2" 9.3# L -80 EUE 8RD production tubing. Set packer with 10K down, 20K up, landed tubing hanger. 08/24/2012 - Friday Drop Prong, Test Casing to 2,000 psi and chart, test tubing to 3,000 psi and chart. Install BPV, nipple down and move out 08/25/2012 - Saturday Finish rigging down and moving rig to new location. • • 08/26/2012 - Sunday Prepping well for production. 08/27/2012 - Monday RIH set X -plug. RIH, set prong. RIH, pull valve from GLM. RIH, set pocket protector. Rig down wireline. RU Pollard hot oil 08/28/2012 - Tuesday RU Pollard Slickline. RIH. Pull pocket protector @ 10,710'. RIH, re -set valve in GLM. RIH, pull prong and X plug. RIH, pull 08/29/2012 - Wednesday Run Gamma Ray and CCL with Pollard. Construction hooking up flow lines and preparing to gas lift well and check for flow. 08/30/2012 - Thursday Y Operations /Production finish hooking up flow line and prepping well for production. Gas lift fluid in well and attempt to flow. 08/31/2012 - Friday RU & RIH with Pollard wireline to perforate. Perforate: 10,906' - 10,916' 2 -1/2" 60 deg phase 6 spf; 10,926' - 10,948' 2 -1/2" • 0 Swanson River Unit , . 114 Well: SRU 331 -27 SCHEMATIC Completion: 8 /27/2012 Hilcorp Alaska, LLC PTD# 100 -148 RKB: 272' / GL: 257' AMSL KB- THF:15.0' Casing Detail Size Type Wt Grade ID Top Btm Hole Cmt Cmt Top 20" J. 1 LSE 20" Conductor - - - Surf 22' - unknown Surf. 22' A6 18 - %" 13 - %" Surface 54.5 J -55 12.615" Surf 1,490' 1,500 sx Surf. 1,497' 7" 29 P -110 6.184 Surf 1,027' 12 2,725' 13 - 3/8 ". +► 7" 29 N -80 6.184 1,027' 2,172' 10-%" 1,490' 2 1 Prod Csg 11,659' 1,000 sx 9,140' CBL I I 7" 26 N -80 6.276 2,172' 8,192' 3 OW ■ 7" 29 N -80 6.184 8,192' 10,695' 7" 29 P -110 6.184 10,695' 11,620' 4 MI ' ' Tubing Detail Cplg OD 3.5" 9.3 L80 2.992 Surface 10,791' • ,! 4.53" S 1• il • Jewelry Detail 6 I ' No. Depth ID OD Item 1 17 2.992" 7" Tubing Hanger w/ IBT x 8rd EUE XO 7 WES i 2 2,296' 2.867" 5.313" Gaslift Mandrel, Camco MM, Port 12 8 gili i 3 4,223' 2.867" 5.313" Gaslift Mandrel, Camco MM, Port 12 CBLTOC • 4 5,827' 2.867" 5.313" Gaslift Mandrel, Camco MM, Port 12 9 MP :1 9,140' . . , 5 7,021' 2.867" 5.313" Gaslift Mandrel, Camco MM, Port 12 ; 1/44 10 1 d 6 7,8 2.867" 5.313" Gaslift Mandrel, Camco MM, Port 12 * 7 8,422' 2.867" 5.313" Gaslift Mandrel, Camco MM, Port 16 `; " t Mandrel, Camco MM - 11 , ; �, 8 9,041' 2.867" 5.313" Gaslift Mandr e , C MM, Port 16 9 9,628' 2.867" 5.313" Gaslift Mandrel, Camco MM, Port 16 12 4 4 "oom' 11 10 10,184' 2.867" 5.313" Gaslift Mandrel, Camco MM, Port 16 141 1 11 10,709' 2.867" 5.313" Gas Lift Orifice, Port Size 20 13 41 1 At 14. 1 .4 12 10,745' 2.813" 5.91" On/ Off Tool, w/ X- Nipple i at 1" '` " 13 10,784' 3" 5.875" Packer Arrowset AS1 -X Mech. .R'* 14 10,789' 2.813" 3.52" X Nipple, (Do not try to set PX plug in this nipple) sok 14 ` : a 15 10,791' 3" 4.5" WLEG r WS - - 16 11,077' Cement Retainer, Capped w/ 10 sx cement .,,,,igt. I' H -4 -4 0 6 Perforation History k4 H -5 Date Zone Top(MD) Btm(MD) Top(MD) Btm(MD) Amt spf Comments A 12 12/11/58 WSO 10,795' 10,796' 10,795' 10,796' 1' 4 4. ' WSO 12/14/58 H -4 10,804' 10,836' 10,804' 10,836' 32' 4 a H -6 12/14/58 H -5 10,849' 10,878' 10,849' 10,878' 29' 4 #H-7 12/11/58 WSO 10,880' 10,881' 10,880' 10,881' 1' 4 Milled K 8/31/2012 H -6 10,906' 10,916' 10,906' 10,916' 10' 6 2.5" Owen retainer • ' w , ° 3 to H -10 8/31/2012 H -7 10,926' 10,948' 10,926' 10,948' 22' 6 2.5" Owen 11,077' < Hemlock 12/09/58 Hemlock 11,038' 11,060' 11,038' 11,060' 22' 4 Open 16 "“ -- , 8/31/2012 H -10 11,050' 11,076' 11,050' 11,076' 26' 6 2.5" Owen 3 ti 44174 ,44_ 12/07/58 Hemlock 11,185' 11,195' 11,185' 11,195' 10' 4 Isolated 7' a, - -_ Hemlock 11,620 TD = 12,046' PBTD = 11,077' Revised By TDF 10/2/2012 • Page 1 of 1 410 Schwartz, Guy L (DOA) From: Schwartz, Guy L (DOA) Sent: Wednesday, August 29, 2012 8:58 AM To: 'Chad Helgeson' Subject: RE: 331 -27 Casing patch change (PTD 100 -148) Chad, Duly noted... no issues. Change in procedure is approved. Guy Schwartz SCANNED MAY 4 2 2013 Senior Petroleum Engineer AOGCC 793 -1226 (office) 444 -3433 (cell) From: Chad Helgeson [mailto:chelgeson @hilcorp.com] Sent: Wednesday, August 29, 2012 7:26 AM To: Schwartz, Guy L (DOA) Subject: 331 -27 Casing patch change Guy, On Sundry # 312 -272 for Swanson River Unit well # 331 -27 workover. We changed our minds on installing the casing patch that was cover the H -4 and H -5 intervals that were previously perforated. Our initial reasoning for installing the patch was to prevent losses when we were perforating the deeper zones, but we were able to establish minimal losses with the 9.3 ppg brine in the well and determined we plugged them up enough that we didn't need to install the patch. Let me know if you have any issues with that. Attached is the proposed completion drawing. Chad Helgeson Operations Engineer Hilcorp Alaska, LLC Office: 907 - 777 -8405 Mobile: 907 - 229 -4824 8/29/2012 1 n • Inson River Unit Well: SRU 331 -27 Proposed Completion: 8/27/2012 13ilcorp Alaska, LLC PTD# 100 -148 RKB: 272' / GL: 257' AMSL KB- THF:15.0' Casing Detail Size Type Wt Grade ID Top Btm Hole Cmt Cmt Top 20" .' 1 f 20" Conductor - - - Surf 22' - unknown Surf. 22 13 - %" Surface 54.5 1 -55 12.615" Surf 1,490' 18-%" 2,725' 1,500 sx Surf. 1,497' r 7 29 P-110 6.184 Surf 1,027' 12 %» 13 -3/8" ., . 10 %" 7" 29 N-80 6.184 1,027' 2,172' 9,140' 1,490' 2 '' Prod Csg 11,659' 1,000 sx 7" 26 N -80 6.276 2,172' 8,192' CBL 3 MB ■ 7" 29 N -80 6.184 8,192' 10,695' 7" 29 P -110 6.184 10,695' 11,620' 4 Tubing Detail CpIgOD 3.5" 9.3 L-80 2.992 Surface ±10,790' 1 1 4.53" 5 MIR MI Jewelry Detail 6 IOW z No. Depth ID OD Item 1 16.50' 2.992" 7" Tubing Hanger w/ IBT x 8rd EUE XO 7 MINI ' IIII 2 2,299' 2.867" 5.313" Gaslift Mandrel, Camco MM, Port 12 8 WE ; 3 4,226' 2.867" 5.313" Gaslift Mandrel, Camco MM, Port 12 CBLTOC III 4 5,829' 2.867" 5.313" Gaslift Mandrel, Camco MM, Port 12 9,140 9 . i • 5 7,023' 2.867" 5.313" Gaslift Mandrel, Camco MM, Port 12 "0 =II ;,• 6 7,835' 2.867" 5.313" Gaslift Mandrel, Camco MM, Port 12 �� 7 8,423' 2.867" 5.313" Gaslift Mandrel, Camco MM, Port 16 11 - - � ' 8 9,043' 2.867" 5.313" Gaslift Mandrel, Camco MM, Port 16 9 9,629' 2.867" 5.313" Gaslift Mandrel, Camco MM, Port 16 12 ' ' ' ;-- 't 1 s 4, 10 10,185' 2.867" 5.313" Gaslift Mandrel, Camco MM, Port 16 11 10,710' 2.867" 5.313" Gas Lift Orifice, Port Size 20 13 + I 1 ' t d 12 ±10,744' 2.813" 5.91" On/ Off Tool, w/ X- Nipple 13 ±10,784' 3" 5.875" Packer Arrowset AS1 -X Mech. } a ., ' 14 ±10,789' 2.813" 3.52" X Nipple, (Do not try to set PX plug in this nipple) , :' 14 1, LIII � ' 15 ±10,790' 3" 4.5" WLEG ' WSO mis 16 11,165' - - Cement Retainer, Capped w/ 10 sx cement (Tag at 11,077') 15 r * � + H -4 Perforation History ' i H - Date Zone Top(MD) Btm(MD) Top(MD) Btm(MD) Amt spf Comments 12/11/58 W50 10,795' 10,796' 10,287' 10,288 1' 4 ,� = WSO 12/14/58 H -4 10,804' 10,836' 10,295' 10,325' 32' 4 - H - 12/14/58 H -5 10,849' 10,878' 10,337' 10,364' 29' 4 f ' ! e 12/11/58 WSO 10,880' 10,881' 10,366' 10,367' 1' 4 0 H - 7 Milled K 2012 H - 6 ±10,902' ±10,910' ±10,386' ±10,394' 8' 6 2.5 "Owen retainer to - H - 10 2012 H -7 ±10,923' ±10,946' ±10,406' ±10,427' 23' 6 2.5" Owen 11,077' 40r Hemlock 12/09/58 Hemlock 11,038' 11,060' 10,514' 10,535' 22' 4 Open `r 2012 H -10 ±11,045' ±11,067' ±10,521' ±10,542' 22' 6 2.5 " Owen ; Hemlock 12/07/58 Hemlock 11,185' 11,195' 10,655' 10,665' 10' 4 Isolated 7" 4 ' - , y — 11,620' r. .' o 4 . 7�w w'L- TD = 12,046' PBTD = 10,975' MAX HOLE ANGLE = 2.0 @ 9.000' SRU 331 -27 Schematic 8- 25- 2012 -doc Undated by CAH 08 -25 -12 Page 1 of 2 . • Schwartz, Guy L (DOA) From: Schwartz, Guy L (DOA) Sent: Thursday, August 16, 2012 8:31 AM To: 'Chad Helgeson'; Regg, James B (DOA); Ferguson, Victoria L (DOA) Cc: donnierhuffman @yahoo.com; Rodney McCoy (rodlmccoy @aol.com); Stan Golis Subject: RE: 331 -27 Update /Change (100 -148) Chad, The changes to the approved sundry are acceptable. The changes include: 1) isolating H-4/5 perfs with a casing patch vs a cmt sqz and 2)perfing with Eline after rig moves off. I will document and update the well file with this email. Regards, Guy Schwartz Senior Petroleum Engineer AI 0 AOGCC 793 -1226 (office) 444 -3433 (cell) From: Chad Helgeson [mailto:chelgeson @hilcorp.com) Sent: Wednesday, August 15, 2012 5:17 PM To: Schwartz, Guy L (DOA); Regg, James B (DOA); Ferguson, Victoria L (DOA) Cc: donnierhuffman @yahoo.com; Rodney McCoy (rodlmccoy @aol.com); Stan Golis Subject: 331 -27 Update /Change Guy, We are changing our work scope on the Swanson River 331 -27 well, (Sundry # 312 -272), as follows. Please let me know if you have any questions or concerns with the plan listed below. Also attached is our proposed completion plan for this well, where we don't plan to perforate the zones until the final completion is set. We have pulled the packers and pumped a pill that has sealed up our losses so we are able to circulate and it has even held pressure. We ran a test packer and tested casing to 10,000ft as we were concerned about the integrity of the pipe because of the tubing condition, and seemed to test fine. We are not going to squeeze the open zones in the well as originally proposed and we do not plan to drill up the cement retainer at 11,123ft. Procedure moving forward will be 1. Drill the bridge plugs with weighted brine, 9.3 ppg. Fluid weight may change after drilling 2nd bridge plug if the lower zone (11,038ft) starts to take fluid. 2. Circulate hole clean, trip out of the hole to clean junk basket and cleanout trip 3. Trip back in the well w/ full gauge mill /casing scraper to circulate the well clean. 4. RU 7" Owen Casing patch and RIH and set across perfs at 10,795 -10 -881. (possible xylene treatment before setting patch) tie -in patch with a -line gamma ray correlated. 5. RU RTTS packer and set at 80ft and test to replace tubing hanger spool for new wellhead. 6. RIH w/ gas lift completion assembly as shown on attached diagram. Mechanical packer on 3- 1/2" tubing. 7. Land tubing hanger, test casing to 1500 psi and chart for 30 min, test tubing to 3,000 psi with a RHCP plug set in X nipple at the bottom of the tubing and chart for 30 min. 8. Set BPV, ND BOP and RU wellhead, test wellhead. 9. RDMO workover rig and equipment. 8/16/2012 • Page 2 of 2 10. RU slickline and swab well to underbalance condition, 20 -30% underbalanced. 11. RU Eline and RIH with 2.5" perforating guns and perforate H -10 (11,045- 11,067), H7 (10,923- 10,946'), and H -6 (10,902 - 10,910). 12. Turn well over to production turn on gas lift and flow well to production. Please let me know if you have any questions or need more information for the activities we have planned moving forward. Thanks Chad Helgeson Operations Engineer Hilcorp Alaska, LLC Office: 907 - 777 -8405 Mobile: 907- 229 -4824 8/16/2012 ` &1d - , . • Swanson River Unit PROPOSED Well: SRU 331 -27 Hileorp Alaska, TLC Last Completed: 1/20/1972 RKB: 272' / GL: 257' AMSL KB- THF: 15.0' Casing Detail } Size Type Wt Grade ID Top Btm Hole Cmt Cmt Top 20" `, 1 , r L 20" Conductor - - - Surf 22' - unknown Surf. ,. N y * J.8 %" 22' " 13-%" Surface 54.5 J -55 12.615 Surf 1,490 1,500 sx Surf. 1,497' 7" 29 P -110 6.184 Surf 1 v 12- 2' 13 - 3/8" .: - 7" 29 N -80 6.184 1,027' 2,172' 10 - %" 1,490' 2 Prod Csg 11,659' 1,000 sx 9140' 7" 26 N -80 6.276 2,172' 8,192' CBL 3 7" 29 N -80 6.184 8,192' 10,695' 7" 29 P -110 6.184 10,695' 11,620' 4 Tubing Detail Cplg OD 3.5" I 9.3 L -80 2.992 Surface ±10,780' 5 Jewelry Detail No. Depth ID OD Item 1 ±15.00' Tubing Hanger 6 2 ±3,500' 2.441" ?" Gaslift Mandrel, Camco MM 3 ±5,500' 2.441" ?" Gaslift Mandrel, Camco MM CBLTOC 4 ±7,000' 2.441" ?" Gaslift Mandrel, Camco MM 9,140' 5 ±8,200' 2.441" ?" Gaslift Mandrel, Camco MM t ;' 8 6 ±9,200' 2.313" ?" Gaslift Mandrel, Camco MM I 7 ±10,500' 2.441" ?" Gaslift Mandrel, Camco MM : 8 ±10,760' 2.441" ?" On/ Off Tool 9 r' 1 9 ±10,770' 2.441" ?" Packer Arrowset 1 -X Mech. 4 10 ±10,785' 5.5" 6.028" Owen Patch 100' (Bottom @ 10,885') 10 11 ±10,790' 2.313" ?" X Nipple 4; WSO ^ d 12 ±10,800' WLEG ', - 13 11,165' - - Cement Retainer, Capped w/ 10 sx cement (Tag at 11,123') : ., 2 c H -4 4 11 ` al ',4 Perforation History - :* Date Zone Top(MD) Btm(MD) Top(MD) Btm(MD) Amt spf Comments • 12 i 12/11/58 WSO 10,795' 10,796' 10,287' 10,288 1' 4 Patched *� 12/14/58 H -4 10,804' 10,836' 10,295' 10,325' 32' 4 Patched • '"1 . 4 12/14/58 H -5 10,849' 10,878' 10,337' 10,364' 29' 4 Patched �� H -5 12/11/58 WSO 10,880' 10,881' 10,366' 10,367' 1' 4 Patched imam • r 't�GK W50 2012 H -6 ±10,902' ±10,910' ±10,386' ±10,394' 8' 6 TCP Jr- _' r a ? H - 6 2012 H - 7 ±10,923' ±10,946' ±10,406' ±10,427' 23' 6 TCP R 12/09/58 Hemlock 11,038' 11,060' 10,514' 10,535' 22' 4 Open t H - 2012 H - ±11,045' ±11,067' ±10,521' ±10,542' 22' 6 TCP 12/07/58 Hemlock 11,185' 11,195' 10,655' 10,665' 10' 4 Isolated ' H -8 13 'JO a,. r.. Hemlock 7 ,. = <- Hemlock 11,620' - 9 •.- TD = 12,046' PBTD = 10,975' MAX HOLE ANGLE = 2.0° @ 9,000' SRU 331 -27 Proposed Plan C 8- 14-2012.doc Undated by TDF 08 -14 -12 • • • b k \ SEAN PARNELL, GOVERNOR U ,L L fL ALASKA OIL AND GAS 333 W. 7th AVENUE, SUITE 100 CONSERVATION COMMISSION n ANCHORAGE, ALASKA 99501 -3539 f PHONE (907) 279 -1433 g FAX (907) 276 -7542 Chad Helgeson Operations Engineer Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 100 Anchorage, AK 99503 Re: Swanson River Field, Hemlock Oil Pool, SRU 331 -27 Sundry Number: 312 -272 Dear Mr. Helgeson: �" '�� 2W 2 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, Ap, / P Cathy '. Foerster Chair DATED this 21 day of July, 2012. Encl. P(16-- 0 • RECEIVED STATE OF ALASKA ti /35.1.43.0412 2 ALASKA OIL AND GAS CONSERVATION COMMISSION 7 Z 7/ / APPLICATION FOR SUNDRY APPROVALS AOG C / 20 MC 25,280 ,iv 1. Type of Request: Abandon ❑ Plug for Redni ❑ Perforate New Pod ❑ v L Repair WeN f •-�i�7 rr''t i Change Approved Program El Suspend p Plug Perforations f �� , Perforate I A e • ,1 Pull Tubing [✓ Time Extension ❑ Operations Shutdown ❑ Re enter Susp. War �`-. Stimulate ❑ AtterCasing ❑ Other. .IBS a . P/'oa [e 2. Operator Name: . Current Wel Class: 5. Permit to Dill Number. Hilcorp Alaska, LLC Development ❑ Exploratory ❑ 100 -148 • 3. A dd r ess : Stratigraphic ❑ Service 0 • 6. API Member. 3800 Centerpoint Drive, Suite 100, Anchorage, AK 99503 50 - 133 - 10156 • 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 cianges: Spacing Exception Required? Yes ❑ No El Swanson River Unit (SRU) 331 -27 9. Property Designation (Lease Number): p cj7 A.-pag yU(, 10. Field / Pool(s): 40' F 9W„$@&10(' /'" 24 Swanson River Field / Hemlock Oil 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): 12,046' , 12,046' • 10,898' 10,898' 10,975' & 11,000' 10,776' & 10,846' Casing Length Size MD TVD Burst Collapse Structural Conductor 22' 20" 22' 22' Surface 1,490' 13 -3/8" 1,490' 1,490' 2,730 psi 853 psi Intermediate Production 11,620' 7" 11,620' 11,620' 604 psi 7,240 psi Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): See Attached Schematic See Attached Schematic 3 -1/2 "; 2 -7/8 "; 2 -3/8" EUE 8RD N -80 10,882' Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): 10,776' MD / 10,776' TVD & 10,846' MD / Baker FH & Baker D 10,846' TVD 12. Attachments: Description Summary of Proposal 19 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch El Exploratory ❑ Development El . Service ❑ 14. Estimated Date for 15. Well Status after proposed work: 7/30/2012 Commencing Operations: 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 Chad Helgeson - 907 - 229 -4824 Printed Name Chad Helgeson . Title Operations Engineer Signature �� Phone 907-777-8300 . Date 772 j// Z. COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: O A 2. -�� — Plug Integrity ❑ BOP Test j Mechanical Integrity Test ❑ Location Clearance ❑ Other: A 3000 e s z, 601° I iS f Subsequent Form Required: / to - APPROVED BY Approved by: . 9 ,/ f/ _ COMMISSIONER THE COMMISSION Date: 7- 2,1 (� BD AUG 0 12011, 7 1 - 7 -g4 -12 n / 11V �` F r 1 -403 Revised 1/2010 /"` O R I G I N l.� L in Duplicate ^, III «` • • • Well Prognosis Well: SRU 331 -27 Hilcorp Alaska, LLC Date: 7/23/2012 Well Name: SRU 331 -27 API Number: 50- 133 - 10156 -00 Current Status: Shut in Gas Injector Leg: N/A Estimated Start Date: August 1, 2012 Rig: AWS #1 Reg. Approval Req'd? 403 Date Reg. Approval Rec'vd: Regulatory Contact: Tom Fouts 777 -8398 Permit to Drill Number: 100 -148 First Call Engineer: Chad Helgeson (907) 777 -8405 (0) (907) 229 -4824 (M) Second Call Engineer: Luke Saugier (907) 777 -8395 (0) (832) 421 -8728 (M) AFE Number: 1221830 Current Bottom Hole Pressure: – 3,117 psi @ 10,841' TVD / (Static survey April 2012 mid pert of 10,841' MD) Maximum Expected BHP: – 6,029 psi @ 11,165' TVD (Using max .54psi /ft gradient for new ✓ H -6,7, & 12 perfs) Max. Allowable Surface Pressure: 1 ,786 psi (Based on actual reservoir conditions and min water cut of 50% (0.385psi /ft) with added Safety Factor of 1,000' TVD ,,.e — 1, 1 (1/J45 of oil cap) Brief Well Summary =. 4 p"- This well was drilled and completed as an oil well in Hemlock benches H -4, H -5, & H -10 in 1958. A workover performed in 1963 isolated the H -10 and reperforate the H -4 & H -5 zones. The well was again worked over in 1971 to convert to gas injection. Gas injection was halted in 1981 and the well has remained shut in to present day. The current workover • Ian is to • ull tubin: and • ackers cement s • ueeze the H -4 and H -5 • ressure test casing, drill out cement, pressure test squeeze, cleanout fill, BPs, perforate H -6 &7 and test zones, if doesn't test, drill cement plug, Reperf /perforate Hemlock intervals (H -4, 5, 6, 7, 10, 12, & 13), and run GL completion. Notes Regarding Wellbore Condition • Well current well status is gas injector /service well. - Brief Procedure: 1. RU slickline. Pressure test lubricator 250psi low /2500psi high. 2. RIH and pull gaslift valve at 10,733'. 3. RD slickline. 4. MIRU Aurora Well Service #1 pulling unit. Circulate well with PW. 5. ND tree, NU 11" BOPE and test same to 250psi low/3,000psi high, annular t 250psi low /3,000psi high. / V /i/ 4 - 0 6 2 4 i l 4 1 v, a c V e ' l ' e - 0 f 8 41 fe 7 - 6. RU to pull tubing hanger and unseat FH packer at 10,776' and POOH with 3 -1/2" x2 -7/8" production tubing down to Model D packer at 10,846'. Jar tubing hanger and packer loose if necessary. a. If unable to pull free, RIH with E -line and use radial cutting torch to cut 2 -7/8" tubing at 10,766'. b. POH with tubing and RIH with overshot and jars and pull FH packer. 7. PU 2 -7/8" rental workstring (P -110), TIH and mill Model D packer at 10,846', POOH. 8. RIH and fish Model D packer and 2 -3/8" tubing tail, POOH. 9. RIH with string mill and dress perforations, tag fill and CO to 10,900'. POOH and LD mill. • • Well Prognosis Well: SRU 331 -27 Hilcorp Alaska, LLC Date: 7/23/2012 10. PU CIBP and cement retainer and RIH. Set the CIBP at 10,895, PU and set cement retainer at 10,750'. 11. RU cement crew, pressure test all lines, connect to tubing. a. Pump approximately 10bbls of G cement sqeueeze, following squeeze procedure. b. RD cement equipment, WOC. SZ - 14 04 5 c. Circulate fluid and cleanup as necessary 12. Pressure test casing to 1500 psi, after cement had time to set. G-r -'°' 13. RU chomper bit and RIH to drill cement and circulate hole clean to the top of Bridge plug at 10,975'. Circulate Bottoms up and pump sweep to get all cement and sand out of hole. 14. Pressure up and test casing and squeeze, chart for 30 min and determine any leak off rate. If no leak off at 1,500 psi. 15. Mix 5% KCI 9.3 ppg NaCI /KCI brine, circulate. 16. RIH and mill bridge plug at 10,975' and bridge plug at 11,000'. Watch for any losses or pressure gains when drilling through bridge plugs. RIH and tag up on cement retainer at 11,165'. Pump sweep and POOH. 17. RU e-line and log well from 11,165- 10,000ft w/ gamma ray and CCL. (18. PU 4 -5/8" or 3 -1/2" TCP guns. to shoot the H6, H7 and H- interval., RIH with guns, pup joint, sliding sleeve or flow sub and ceramic plug, pup joint, Arrowset mechanical packer, pup joint with orijofflool, 1 gas lift mandrel at 10,000'. ) 19. Circulate and filter brine to 10 micron filters, check brine weight. C / 20 Set packer at 10,760'. . - t 21. Pressure test packer to 1500 psi. � �i' 22. RU slickline and RIH and open sliding sleeve. 23. Swab well down to 500 psi underbalanced. 24. RU Test equipment or flow line to production from tubing. 25. RU e-line and ensure guns are on depth. 26. Secure well and fire TCP Guns. 27. Monitor well and check for pressure influx. 28. Test well to see if it will flow, if well does not flow on its own, RU swab cups and RIH and tag fluid depth. Swab well to tank to determine if any oil is coming from formation. Wait details from engineer. a. If well flows on its own, SI and RD test equipment and swab equipment. b. RU slickline to RIH and pull TCP bar and close the sliding sleeve. Set plug in X- nipple. / c. Pressure test casing and tubing to 2,000 psi. y s d. Use GL mandrel to circulate fluid ���° e. Circulate fluid and release from on /off tool. °I 0- „I f. LD 2 -7/8" work string, PU GL completion and 3 -1/2" tubing. Run completion. g. Circulate hole, space out tubing and land production tubing on on /off tool and pressure test packer. RD BOP and install tree as necessary. > h. RDMO workover rig and equipment. 1 i. Turn well over to roductinr 29. If well doesn't test, RD test and swab equipment, shoot fluid level to determine depth of fluid. ,��� 30 RIH w /slickline and pull GL mandrel dummy. CA 1. Circulate the well with brine. Release packer and POH with completion fluid, monitoring well cc r - I9 and filling as coming out of the hole: '- 32. LD completion, test equipment and TCPguns. • • Well Prognosis Well: SRU 331 -27 Hilcorp Alaska, LLC Date: 7/23/2012 33. RIH and mill cement and retainer at 11,165'. Tag bottom, be sure to get below 11,215 preferred is 11,250. 34. Circulate hole clean, pump sweep, circulate filtered brine. POH LD work string tor 35. RU a -line, RIH and log well from TD to 10,000'. -- r 36. PT lubricator to 3,000 psi. �� P, 37. PU 3 -3/8 or 3 -1/2" guns and perforate H -13, H -12, H -10, H -5, and H4 inte als (106 ft) 38. Monitor well for pressure increases. 39. RD a -line. 40. RU and RIH 3 -1/2" completion, packer, GLV's per design on 3 -1/2" tubing. Set packer at +/- 10,750'. 41. Land tubing hanger, Test packer, Set BPV, ND BOP. 42. RU test tree, RDMO workover rig and equipment. 43. Turn well over to production. Attachments: 1. As -built Schematic 2. Proposed Schematic 3. BOP Schematics • • Estimated BHP 6,029 psi TVD 11,165 ft Oil Water Cut 50 % Cap Safety Factor: 1,000 (TVD ft) oil cap Fluid Gradient 0.385 psi /ft MASP 1785.5 psi Water Cut Fluid Fill in data in highlighted boxes 4. 40 Swanson River Unit SCHEMATIC Well: SRU 331 -27 Ililcurp Alaska, LLC Last Completed: 1/20/1972 RKB:272' / GL: 257'AMR Casing Detail KB - THF: 15.0' g Size Type Wt Grade ID Top Btm Hole Cmt Cmt Top 1 20 „ 20" Conductor - - - Surf 22' - unknown Surf. 22' '' s " *, * Vi e, Surface 54.5 J -55 12.615" Surf 1,490' 18 /8 1,500 sx Surf. 1,497' s 12%" c 7" 29 P -110 6 S 1 2,725 13 -3/8" .i. 7 29 N -80 6.184 1,027' 2,172' 10 -/s 1,490' Prod Csg 11,659' 1,000 sx 9,140' CBL 7 " 26 N -80 6.276 2,172' 8,192' 7 " 29 N -80 6.184 8,192' 10,695' 7 " 29 P -110 6.184 10,695' 11,620' Tubing Detail Cplg OD 3 /z ", EUE 8RD 9.3 N -80 2.992 Surf 10,700' 4.500" CBL TOC 2 % ", EUE 8RD 6.5 N -80 2.441 10,700' 10,846' 3.xxx" 9,140' 2 % ", EUE 8RD 4.7 N -80 1.995 10,846' 10,882' 3.063" t. Jewelry Detail No. Depth ID OD Item S G '1" � v� 1 15.00' 2.992" 4.500" Tubing Hanger � 2 10,700' 2.441" ?" XO, 3 -1/2" to 2 -7/8" 2 K (t , ' 3 10,733' 2.441" ?" Gaslift Mandrel, Camco MM s°' 4 10,776' 2.441" ?" Packer, 7" Baker FH . ' 3 m'a:' i evl /Q�/v�i I 5 10,783' 2.313" ?" Otis 'S' Nipple Position #1 III r., i 6 10,799' - - 12' Tubing Punch (10,799' - 10,814') 47 shots (Shot 4/09/11) K-'11 4 , _ 7 � IO 7'7 ' 7 10,816' 2.441" ?" Gaslift Mandrel, Camco MM `v r 1 , Dv/ 8 10,845' ?" ?" Camco 'D' Nipple Position #1 i 9 10,846' ?" ?" Packer, 7" Baker Model D WSO 10 10,975' - - Bridge Plug, Baker Model N (Set 5/10/63) H 4 11 11,000' - - Bridge Plug, Baker Model K Imo ' 12 11,165' - - Cement Retainer, Capped w/ 10 sx cement (Tag at 11,123') i Perforation History y✓► i / i ' •F S h Date Zone Top Btm Amt spf Comments D h . . .t 9 ' 12/11/58 WSO 10,795' 10,796' 1' 4 Open _ i ■ f E : 12/14/58 H -4 10,804' 10,836' 32' 4 Open .. Yin. 12/14/58 H -5 10,849' 10,878' 29' 4 Open Tag fill ' ./ 10,898' RK '! 881' 1' 4 Open 12/11/58 WSO 10,880' 10 - S O 4/04/11 B\ . Z 5e, I- I Df ' 12/09/58 Hemlock 11,038' 11,060' 22' 4 Isolated 101S f V 12/07/58 Hemlock 11,185' 11,195' 10' 4 Isolated io9t 10 'la 11 - 7"-1 ` 7.7 , , C 3 ?./ la'h s (j n ii/ S -10'75-4 ) % � ' - .- bb, 45 Hemlock . 11 it 12 --• .__- lc°nec it 7 « Hemlock 11,620' r, - r,4 ; d _ . TD = 12,046' PBTD = 10,975' MAX HOLE ANGLE = 2.0° @ 9,000' SRU 331 - 27 Schematic 7 -17 -2012 Updated by TDF 07 -18 -12 14 • 4 k 1 • Swanson River Unit PROPOSED Well: SRU 331 -27 Hilcorn Alaska, LLC ii_t, /7/9 Last Completed: 1/20/1972 5 `sf e /tsE RKB: 272' / GL: 257' AMSL KB- THF:15.0' Casing Detail Size Type Wt Grade ID Top Btm Hole Cmt Cmt Top 20 „ , ' 1 - 4_ 20" Conductor - - - Surf 22' - unknown Surf. 22' , ': w,. 18 - %" 13 - %" Surface 54.5 J -55 12.615" Surf 1,490' 1,500 sx Surf. f . . 1,497' 12-3/4" f. ? 7 " 29 P -110 6.184 Surf 1,027 2,725' 13 -3/8" . Y .� s 7" 29 N -80 6.184 1,027' 2,172' 10- "s" 1,490' Prod Csg 11,659' 1,000 sx 9,140' CBL 7" 26 N -80 6.276 2,172' 8,192' 7" 29 N -80 6.184 8,192' 10,695' era, 7" 29 P -110 6.184 10,695' 11,620' + Tubing Detail Cplg 2 - %8" 7.8 P -110 2.323 Surface 10,780' CBL TOC 2- %" 6.5 L -80 2.44 10,780' 10,900' • 9,140' ' I. "A Jewelry Detail No. Depth ID OD Item 6 : t 1 ±15.00' Tubing Hanger .* 2 ±10,750' 2.441" ?" Gaslift Mandrel, Camco MM 3 ±10,770' 2.441" ?" GOn/ Off Tool 2 ink i ,." . s ^, 4 ±10,780' 2.441" ?" Packer Arrowset 1 -X Mech. Tii' ' " 3 Ili w F 44' 5 ±10,850' 2.313" ?" X Nipple " 6 ±10,870' 10' Sliding Sieve 5 1 4 7a ±10,902' TCP Guns • t4 7b ±10,923' TCP Guns ",' 7c ±11,045' TCP Guns , WSO 8 11,165' - - Cement Retainer, Capped w/ 10 sx cement (Tag at 11,123') w 5 - 3 " '" " - a Perforation History 6 FR V -1 Date Zone Top(MD) Btm(MD) Top(MD) Btm(MD) Amt spf Comments s j+ 12/11/58 WSO 10,795' 10,796' 10,287' 10,288 1' 4 Squeezed '- ' 12/14/58 H-4 10,804' 10,836' 10,295' 10,325' 32' 4 Squeezed s. ;,-' ,T4 R a4, 12/14/58 H -5 10,849' 10,878' 10,337' 10,364' 29' 4 Squeezed ` , H - 12/11/58 WSO 10,880' 10,881' 10,366' 10,367' 1' 4 Squeezed ' 2012 H - ±10,902' ±10,910' ±10,386' ±10,394' 8' 6 TCP 1I s R Eiji WSO 2012 H -7 ±10,923' ±10,946' ±10,406' ±10,427' 23' 6 TCP • 7a E. �'w = ,-= H - 12/09/58 Hemlock 11,038' 11,060' 10,514' 10,535' 22' 4 Open 2012 H -8 ±11,045' ±11,067' ±10,521' ±10,542' 22' 6 TCP °° 7b A .H -7 A. 12/07/58 Hemlock 11,185' 11,195' 10,655' 10,665' 10' 4 Isolated , 7c ma H 8 7 Hemlock • / , , 7 " . _-,_ ' - -- Hemlock 11,620' `f . 0 ,:; - a,,,S TO = 12,046' PBTD = 10,975' MAX HOLE ANGLE = 2.0° @ 9,000' SRU 331 -27 Proposed Plan B 7- 26- 2012. Undated by TDF 07 - - • � • PROPOSED Swanson River Unit Well: SRU 331 -27 Hamm) Alaska, LLC Last Completed: 1/20/1972 RKB: 272' / GL: 257' AMSL KB- THF: 15.0' Casing Detail Size Type Wt Grade ID Top Btm Hole Cmt Cmt Top 20" j: 1 20" Conductor - - - Surf 22' - unknown Surf. 22' 1 +', 13- 18 - %" 13 - 3/8" _ �„ Surface 54.5 J -55 12.615" Surf 1,490' 1 497 1,500 sx Surf. 1,490' 12-%" 7" 29 P -110 6.184 Surf 1,027' 2,725 2 r 10 - %e " 7" 29 N -80 6.184 1,027' 2,172' 11,659' Prod Csg 1,000 sx 9,140' CBL 3 1 7" 26 N -80 6.276 2,172' 8,192' 7" 29 N -80 6.184 8,192' 10,695' 4 7" 29 P -110 6.184 10,695' 11,620' Tubing Detail Cplg OD 3 1/2", EUE 8RD 9.3 N -80 2.992 Surf 10,786 4.500" 5 Mr ' I Jewelry Detail 1 CBL TOC 6 ' No. Depth ID OD Item 9,140' 1 15.00' 2.992" 4.500" Tubing Hanger 7 WM ' 4 `' ° 2 ±3,300' 2.441" ?" Gaslift Mandrel, Camco MM 'b!, ,.► 3 ±5,600' 2.441" ?" Gaslift Mandrel, Camco MM 8 �j 4 ±7,100' 2.441" ?" Gaslift Mandrel, Camco MM 5 ±8,300' 2.441" ?" Gaslift Mandrel, Camco MM 0 1 6 ±9,100' 2.441" ?" Gaslift Mandrel, Camco MM it hi 7 ±9,700' 2.441" ?" Gaslift Mandrel, Camco MM ■ 10 l I l 44+ 8 ±10,300' 2.441" ?" Gaslift Mandrel, Camco MM 5$ 11 9 ±10,733' 2.441" ?" Gaslift Mandrel, Camco MM 10 10,776' 2.441" ?" Arrowset Mechanical Packer with on/ off Tool �11A WSO 11 10,786' 2.313" ?" WLEG s1 . x ,; H -4 J Perforation 0. '0 Zone Top(MD) Btm(MD) Top(TVD) Btm(TVD) Amt spf Comments Date ,. H - WSO 10,795' 10,796' 10,287' 10,288' 1' 4 SQZ Future 10,804' 10,836' 10,295' 10,325' 32' 4 SQZ Future Vi i+ ��y WSO H-4 4 ±10,810' ±10,842' ±10,301' ±10,330' 32' 6 WL Future ' 1 10,849' 10,878' 10,337' 10,364' 29' 4 SQZ Future 5$ # H -6 H -5 H-7 ±10,858 ±10,887 ±10,345' ±10,372' 29' 6 WL Future 3 ,„ WSO 10,880' 10,881' 10,366' 10,367' 1' 4 SQZ Future H emlock H ±10,902' ±10,910' ±10,386' ±10,394' 8' 4 TCP Future ' H -7 ±10,923' ±10,946' ±10,406' ±10,427' 23' 4 TCP Future H -10 Hemlock 11,038' 11,060' 10,514' 10,535' 22' 4 Open 12/09/58 H -10 ±11,045' ±11,067' ±10,521' ±10,542' 22' 4 WL Future :14 ti H -12 ±11,155' ±11,165' ±10,625' ±10,635' 10' 4 TCP Future Hemlock 11,185' 11,195' 10,655' 10,665' 10' 4 Open 12/07/58 q Hemlock H -13 ±11,192' ±11,205' ±10,662' ±10,675' 13' 6 TCP Future H -12 r -L.c.. 7" a H -13 t .lw^"-'' 11,620''Apt e.1.:w4 TD = 12,046' PBTD = 11,450' MAX HOLE ANGLE = 2.0 @ 9,000' SRU 331 -27 Proposed 7 -18 -2012 Updated by TDF 07 -20 -12 • • Estimated BHP 6,029 psi TVD 11,165 ft Oil Water Cut 50 % Cap Safety Factor: 1,000 (TVD ft) oil cap Fluid Gradient 0.385 psi /ft MASP 1785.5 psi Water Cut Fluid Fill in data in highlighted boxes • 0 Aurora Well Service 3000# BOP Stack 1 0' 1 Rig Floor I Flow Nipple j 1 I 6 '5" -- i ► 11" Shaffer 3K g' 5" 1 ■ — 11" Shaffer 3K PIPE RAMS �. — – f -_. -_ I L _f 11 Shaffer 3K � . 9' 6" 1 BLIND RAMS ! r 1 ( ii i Choke Line i Kill Line 111'1" —♦ /.1*- ilia 11" 3K /� i♦ S ' kip( _ 3ili(�: =1a� 'l KILL SPOOL X : 1 - lip {ii: -1)Ulm ® 11" 30004 C iiil D S 14' in 1 Starting Head — 11 ", 3000# t i" 3ax1;� �� ..--- .. A - 31/16" 5K HCR valve B - 3 1/16" 5K Gate valve C .. 3 1/16" 5K Gate valve 1 Varies 1 ► i D - 3 1/16" 5K HCR valve ® E - 3" 200# Ball Valve Page 1 of 2 Schwartz, Guy L (DOA) From: Chad Helgeson [chelgeson @hilcorp.com] Sent: Thursday, July 26, 2012 3 :10 PM To: Schwartz, Guy L (DOA) Cc: Ferguson, Victoria L (DOA) Subject: RE: SRU 331 -27 (PTD 100 -148) Attachments: SRU 331 -27 FLOWBACK.PDF I would flow back with tubing in the BOP. The attached drawing may show it better. The completion drawing was to show you what the completion would look like at the bottom, sorry about the surface confusion. The attached would have tea TIW floor safety valve with a pump in sub. All of this equipment would be pressure tested before we would fire the guns. If the well test is successful. I would plan to close the sliding sleeve, set a plug fill the tubing with kill weight fluid and remove the workstring, and run a permanent completion leaving the packer in place and isolated. We would then set the tree pressure test tubing and packer completion again and turn the well over to production. If the test doesn't work, we will determine our bottom hole pressure, before proceeding with the remainder of the well work. Let me know if you have any other questions. Thanks Chad From: Schwartz, Guy L (DOA) [mailto:guy.schwartz @alaska.gov] Sent: Thursday, July 26, 2012 2:55 PM To: Chad Helgeson Cc: Ferguson, Victoria L (DOA) Subject: RE: SRU 331 -27 (PTD 100 -148) Chad, Are you rigging up the production tree for the TCP flow test or still have BOP rigged up... your well sketch shows the tubing landed in a hanger? Guy Schwartz Senior Petroleum Engineer AOGCC 793 -1226 (office) 444 -3433 (cell) From: Chad Helgeson [mailto:chelgeson @hilcorp.com] Sent: Thursday, July 26, 2012 1:07 PM To: Schwartz, Guy L (DOA) Cc: Ferguson, Victoria L (DOA) Subject: RE: SRU 331 -27 (PTD 100 -148) Forgot the attachment Sorry 7/26/2012 Page2of2 • From: Chad Helgeson Sent: Thursday, July 26, 2012 1:07 PM To: 'Schwartz, Guy L (DOA)' Cc: Ferguson, Victoria L (DOA) Subject: RE: SRU 331 -27 (PTD 100 -148) Attached is a wellbore sketch showing the TCP guns, etc. I am waiting for my sketch of the surface test piping to be finished this afternoon, but will get that to you as soon as possible. My plan on the surface testing is to connect a TIW on the top of the tubing and run hardline to the choke manifold with an automated HCR type valve or safety valve (rental) on the inlet to a choke test manifold. This will be a separate choke manifold from the rig manifold. The MASP is the most conservative estimate for safety purposes, there is the possibility of virgin pressure in the H6 and H7 zones. If we plan for the most pressure we shouldn't be caught in a bind and be ready to handle it. I will give you a call to discuss to see how things are going for you on this review and if you have any other concerns, I might need to address today. Chad From: Schwartz, Guy L (DOA) [mailto:guy.schwartz @alaska.gov] Sent: Wednesday, July 25, 2012 8:42 AM To: Chad Helgeson Cc: Ferguson, Victoria L (DOA) Subject: SRU 331 -27 (PTD 100 -148) Chad, Can you elaborate a bit more on the TCP peng and flow test you are planning on 331 -27. Specifically, how are you rigging up the surface flow equipment and will there be any type of Surface safety valve right at the rig floor. There needs to be some sort of auto shutdown device in the system. I would like to see a TCP BHA diagram, and surface flowback diagram. Are you fairly confident in your calculated MASP. Do you have any pressure data from offset wells in the lower Hemlock zones... H -12 H 13? Guy Schwartz Senior Petroleum Engineer AOGCC 793 -1226 (office) 444 -3433 (cell) 7/26/2012 SRU 331 -27 FLOWBACK DIAGRAM PUMP IN ' 2" HARD LINE • S UB ` ►1 TIW 7/ , SAFETY i $ s f'-"" VALVE �, :- t ` R i�� v G FLOOR — — — TO TEST SEPARATOR ACCUMULATOR TANK I 11 1111 ILUI BOP 411 eic' '" SAFETY I �1 all. STACK I VALVE ---\ I ,,,TI___1><1 H . , I p I II I I I t ►/ • • pr INDEX NO. 100 / /y8 UNIT NO. 510 -35 PN. 510 -35 thru 512 -95 W eatheriord® c_c R UJ 33 a? DATE March 27, 2002 Completion Systems II T-2 On-OffTool --_t The Weatherford T -2 On -Off Tool allows the tubing string to be disconnected above a packer. It contains an internal lock profile for landing a wireline plug to provide zonal isolation below the packer. The T -2 has two basic components: the overshot, which is mounted on the tubing string, and the stinger, which is mounted to the packer. The overshot disengages with either standard left -hand release or optional right -hand 1 . quarter -turn release. Shear -up or shear -down positions are compatible with packer setting and retrieving styles. The washover shoe on the overshot allows cutting through debris. The seals on the On -Off Tool are retrieved with the overshot to allow for redress. The stinger is available with all common wireline profiles, and allows the use of industry standard blanking plugs, standing valves, and regulators. SEAL Features • Standard left-hand release, optional right -hand release • Bonded seals allow multiple disconnects without retrieval • Can be pinned in shear -up or shear -down position • Standard Baker -Type F and R nipple profiles • Optional Otis -style nipple profiles • Washover shoe cuts through debris • Seals retrieved with overshot for redress SCANNED A�` • Variety of materials available Benefits s -,, ce, • Allows tubing retrieval without disturbing the packer • Allows full - pressure testing at surface • Quarter -turn release simplifies operation • Simple design is rig - operator friendly • Rugged and dependable design • Allows use of packer as bridge plug Applications • Zonal isolation above packer • Tubing retrieval without disturbing packer • Temporary abandonment of lower zones _ • Mechanical -, hydraulic- or wireline -set packer completions Weatherford products and services are subject to Weatherfords standard terms and 1 of 13 conditions. For more information concerning the full line of Weatherford products and services, please contact your authorized Weatherford representative. Unless noted otherwise, trademarks and servicemarks noted herein are the property of Weatherford. ® 2002. Weatherford. All rtahts reserved. Form so-s (JUNE 1990) BUREAU OF LAND MANAGEMENT SUNDRY NOTICES AND REPORTS ON WELLS Do not use this form for proposals to drill or to deepen or reentry to a different reservoir. Use 'APPECATION FOR PERMIT-' for such proposaJs SUBMIT IN TRIFLICA TE 1. Type of Well Oil Gas I~ Well [:~ Well r-! Other 2. Name of Operator Union Oil Company of California (dba Unocal) 3. Address and Telephone P. O. Box 196247, Anchorage, AK 99519 (907) 276-7600 4. Location of Well (Footage, Sec., T., R., M., or Survey Description) Swanson River Unit -- 14 Wells Soldotna Creek Unit -- 7 Wells FORM APPROVED Budget Bureau No. 1004-0135 Expires: March 31, 1993 5. Lease Designation and Serial No. 6. ff Indian, Allottee or Tribe Name 7. If Unit or CA, Agreement Designation Swanson River/ Soldotna Creek Units 8. Well Name and No. 9. APl Well No. 10. Field and Pool, or Exploratory Area Swanson River Field 11. County or Parish, State Kenai, Alaska 12. CHECK APPROPRIATE BOX(s) TO INDICATE NATURE OF NOTICE, REPORT, OR OTHER DATA TYPE OF SUBMISSION TYPE OF ACTION Notice of Intent r-] Subsequent Report Final Abandonment [--] Abandonment I-I Change of Plans ~ Recompletion [::] New Construction [-] Plugging Back [-] Non-Routine Fracturing l-] casing Repair [-] Water Shut-Off [] Altering Casing r-I Conversion to Injec'~on [:~ Other Temporarily Abandon I--1 Dispose Water (Note: Report results of multiple co. repletion on Well Completion or Re<x)mplel~on Relx~t and Log form.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details, and give pertinent dates, including estimated date of starting any p~oposed work. if well is directionally drilled, give subsudace locations and measured and true vert~ai depths for all markers and zone pertinent to this work.)* As described in attached letter, Unocal requests that the following wells have a temporarily abandoned status for the twelve month period, April 1,1996 to March 31,1997: Soldotna Creek Unit ~. j¢J SCU 21-8 31SCU 34-9 ~' ) ~'SRU 212-10 {OI" 4'/,~SCU34-8 [-~SCU41B-9 (.g~) o~-~SRU 12-15 (eO.' / SCU 243-8i [.~=CU 14-34 00-] ~)SRU 14-15 ~ i-cI~'SCU 13-9 ~,.~.~,~ 6'J.,'.~_O SRU41A-15 O0 * High GOR well that may be produced intermittently Swanson River Unit sRu 2 2-27 ./.I SRU 23-27 SRU331-27/OO_.,'_l~i~ SRU 34-28 ~ 7_ SRU 43-28 Gl'" ~ SRU 21-33WD ~ ~'",~, APR 0 't SRU 24-33 14. I bereby certify th~ Itm foregoing is true and c(xrect. (This space for Federal and'~ffice use) Dennis L Groboske 'r~e Petroleum Engineer Date 3/29/96 Approved by Title Date Coa~ of approval, if any: T'~e 18 U.S.C. Se~on 1001, makes ira crime for any pemon knowingly and willfully to make to any department or agency of lhe United States any false, fictitious or fraudulerl statements or represenlalions as to any matter within its jurb<~on. *See Instruction on Reverse Side Attachment No. 1 Swanson River Field Proposed Temporarily Abandoned Wells: Total 21 Wells Twelve Month Period: April 1, 1996 to March 31, 1997 Shut-in Wells under Evaluation for Shut-in Wells during Field Blowdown Rate Potential P&A Shallow Gas Potential and 'Hemlock Only' P&A Hemlock Producers Future Shallow Gas Producer with the Hemlock Abandoned SCU 34-8 SCU 243-8 SCU 13-9 SCU 41B-9 SRU 21-33WD SRU 34-28 SRU 43-28 SRU 212-10 SRU 212-27 SRU 12-15 SRU 41A-15 SRU 23-27 SRU 331-27 SCU 14-34 SCU 21-8 SCU 34-9* SRU 14-15 SRU 43A-15 SRU 14-22 SRU 23-22 SRU 24-33 7 Wells 2 Wells 5 Wells *.~,h GOR well that may be produced intermittently 2 Wells 5 Wells ATTACHMENT 2 SWANSON RIVER FIELD Wells with Temporarily Abandoned Status Change Removed from 1996 Temporarily Abandoned Status · SCU 34-4 · SCU 43A-4 Recompleted in Tyonek G1 and G2 zones Recompleted in Tyonek G1 and G2 zones · SCU 13-4 Workover to remove tubing fish. Currently producing from Hemlock · SCU 23B-3 Returned to full time production · SCU 314-3 Returned to full time production · SCU 43-9 Returned to full time production · SCU 23-15 Returned to full time production Additions to 1996 Temporarily Abandoned Status · SCU 13-9 Recompleted in Tyonek G2 zone Iow rate oil producer. tkE..G IvE. D APR 0 1 1996 Unocal North Amq~ ~' Oil & Gas Division~ Unocal Corporation ~ 909 West 9th Ave., P.O. Box 190247 Anchorage, Alaska 99519-0247 Telephone (907) 276-7600 UNOCAL ) Alaska Region March 31, 1994 Re: Mr. Joseph A. Dygas Bureau of Land Management Alaska State Office 222 West 7th Avenue #13 Anchorage, Al( 99513-7599 · .!994 Sundry Notice Request for TA Wells..i,.n..Swanson River.. Field Dear Mr. Dygas: Attached is a Sundry Notice, requesting approval to temporarily abandon (TA) 30 wells in the Swanson River Field for a period of 12 months. This Sundry Notice is being submitted t° comply with 43 CFR 3162.3-4, paragraph (c) of the Bureau of Land Management Regulations. As shown on the Sundry Notice, we are'requesting that the 12 month approval period for the proposed TA wells coincide with the Plan Period of the Thirtieth Plan of Development and Operations for the Swanson River Field; i.e. April 1, 1994 to March 31, 1995. Two information sheets are attached with this Sundry Notice request. Attachment I lists the proposed TA wells using the same. format as submitted last year. The two general categories are shut-in wells being held for evaluation for current uses or disposition and wells being held for future uses during field blowdown. Attachment 2 gives a brief explanatinn fnr ~.~rh ,.,~11 th'-t h-- , I- Mr. Joseph A. Dygas March 31, 1994 Page 2 As was the case last year, SCU 43-4WD is not included on the proposed TA li~t since it is a standby water disposal well used only seasonally. If you have any questions concerning this Sundry Notice, please call me at 263-7816. DLG:dma 7~,,.Dennis L.' ~~r(~ske Petroleum Engineer Attachment cc: L.R. Dartez, Marathon Oil Company D. W. Johnston, Chairman, AOGCC Attachment NO, ! Swanson River Field Proposed Temporarily Abandoned Wells: Total 30 Wells Twelve Month Period: April 1, 1994 to March 31, 1995 Shut-in Wells under Evaluation for Rate Potential P & A 5SCU 13-4 u~'-I~ SRU 212-10 Shallow Gas Potential and 'Hemlock Only' P & A <>SCU 34-4 ~(-oS SRU 23-15 ~SCU 341-8 ~--5o SRU 41A-15 SRU 34-28 ez.-5~ SRU 14-22 SRU 43-28 ~-['~SRU 23-22 ~ SRU 32-33WD/~I-~SRU 212-27 t SCU 243-8 c~-;q~ SRU 331-27 SRU 21-33WD~0--Z~SRU 12-15 Ioo-~&SCU 14-34 &0-qc/SRU 23-27 SRU 14A-33 Shut-in Wells during Field Blowdown Hemlock Producers bz-['l SCU 21-8' Future Shallow Gas Producer with the Hemlock Abandoned °O-lU~L~ SRU 14-15 ~\-=t~ SCU 13-9 c~0-u~t SRU 34-15 (ot-~ff SCU 34-9' SRU 43A- 15 ~q'-~USCU 23B-3' %ct-bb SRU 432-15 ~u~-~q SCU 43A-4' -~_-o-~SRU 24-33 SCU 21A-4' 8 Wells 8 Wells 3 Wells 6 Wells 5 Wells *High GOR wells that may be produced intermittently RECEIVED APR - 1 1994 ~ska Oil & ~as Cons. Commission Anchorage Attachment 2 Swanson River Field Wells with Temporarily Abandoned Status Change Additions to 1994 Temporarily Abandoned Status SCU 12-15: Shut-in gas lift producer with casing communication. Evaluate for repair or abandonment. · SCU 21-33WD: Shut-in due to wireline fish in tubing. Workover candidate. ,R..emoved from 1994 Temp,o, rarily Abandoned Status · SRU 24A-9: Returned to full time production after workover. · SRU 21-3: Returned to full time production due to commencement of Blowdown in field. · SRU 33-5: Returned to full time production after workover. , Form 3160-5 (JUNE 1990) UNl'r~' ATES DEPARTMENT OF THE INTERIOR BUREAU OF LAND MANAGEMENT SUNDRY NOTICES AND REPORTS ON WELLS Do not use this form for proposals to drill or to deepen or reentry to a different reservoir. Use 'APPUCATION FOR PERMIT-' for such proposals SUBMIT IN TRIPLlCATE 1. Type of Well Oil Gas [~ Well [~ Well ~ Other 2. Name of Operator Union Oil Company of California (dba Unocal) 3. Address and Telephone P. O. Box 196247, Anchorage, AK 99519 (907) 27.6-7600 .. 4. Location of Well (Footage, Sec., T., R., M., or Survey Description) Swanson River Unit --- 19 wells Soldotna Creek Unit --- 11 wells FORM APPROVED Budget Bureau No. 1004-0135 Expires: March 31r...1993 5. Lease Designation and Serial No. 6. If Indian, Allottee or T~ibe Name · . .. 7. If Unit or CA, Agreement Designation Swanson River/ Soldotna Creek Units 8. Well Name and No, 9. APl Well No. 10. Field and Pool or Exl~oratory Area Swanson River Field 11. County or Parish, State Kenal, Alaska 12. CHECKAPPROPRIATE BOX(s) TO INDICATE NATURE OF NOTICE, REPORT, OR OTHER DATA TYPE OF SUBMISSION TYPE OF ACTION Notice of Intent Subsequent Repo~ Final Abandonment [-] Abandonment ~ Recompletion r-] Plugging Back ~ Casing Repair ~ Altering Casing r~ Change of Plans ~ New construction 0 Non-Routine Fracturing I-] Water Shut-Off r'*] Conversion to Injection Other T .emporarily Abandon J-1 Dispose Water (Note: Report reat~ el' multiple oonmplelfl:m o~ Well 13. Descn'be Proposed or Completed Opemtiorm (Cleady slate all perlirmnt delails, and give pe~Idnent dates, trmluding eslimated date of slmlJng any i~opoeed wodc AS described in attached letter, Unocal requests that the following wells have a temporarily abandoned status for the twelve month period, April 1994 to March 31, 1995: Soldotna Creek Unit · -% }' * SCU 23B-3 SCU 243-8 <~ I SCU 13-4 SCU 341-8 <J ~ * SCU 21A-4 SCU 13-9 ~i SCU 34-4 * SCU 34-9 5' ! * SCU 43A-4 SCU 14-34 / --~//-.-* SCU 21-8 *Hinh ~C)R w .Ik' tP t n- ,. k Swanson River Unit ~' ,' SRU 212-10 .,,~SRU 14-22 $ / SRU 43-28 %t:$~, SRU 14-15//-:I,~RU 12-15 ~ I 8RU 14A-33 ~ 8RU 23-15 ~ SRU 23-22TU..';pSRU 24-33 ~u~I:'SRU 34-15 31 SRU 23-27. '*' 8RU 32-33VVD %i SRU 41A-15}~SRU 212-27 SRU 21-33WO ~ SRU 43A-15,.%~ SRU 331-27 ~ u~e SRU 432-15 ~l SRU 34-28 Alaska Region Unocal North Americ,~' PU?(~-~'° xC~ ~q~o r2a4ticn Anchorage, Alaska 99519-0247 Telephone (907) 276-7600 ~'OMM UNOCAL oa, - r(~~ ~OL ASST~ ~p~(~.~ ~ ~. ~TAT-TECH~ March 24, 1993 ~ ff/¢ ~T'TEC~ FILE Mr. Joseph A. Dygas Bureau of Land Management Alaska State Office 222 West 7th Avenue #13 Anchorage, AK 99513-7599 Re: 1993 Sundry Notice Request for TA Wells in Swanson:,iRiver:Fielc[ Dear Mr. Dygas: Attached is a Sundry Notice, requesting approval to temporarily abandon (TA) 31 wells in the Swanson River Field for a period of 12 months. This Sundry Notice is being submitted to comply with 43 CFR 3162.3-4, paragraph (c) of the Bureau of Land Management Regulations. As shown on the Sundry Notice, we are requesting that the 12 month approval period for the proposed TA wells coincide with the Plan Period of the Twenty-Ninth Plan of Development and Operations for the Swanson River Field; i.e. April 1, 1993 to March 31, 1994. These concurrent time periods will greatly simplify future TA Sundry Notice and Plan of Development and Operations preparation. Two information sheets are attached with this Sundry Notice request. Attachment 1 lists the Proposed TA wells using the same format as submitted last year by ARCO. The two general categories are shut-in wells being held for evaluation for current uses or disposition and wells being held for future uses under field blowdown. Mr. Joseph A. Dygas March 18 Page 2 As was the case last year, SCU 43-4WD is not included on the proposed TA list since it is a standby water disposal well used only seasonally. If you have any questions concerning this Sundry Notice, please call me at 263-7816. Yours very truly, Petroleum Engineer DLG:sr Attachment cc: L.C. Smith, Chairman, AOGCC L. R. Dartez, Marathon Oil Company Form 3 I [June 1990) UNITED STATES DEPARTMENT OF THE INTERIOR BUREAU OF LAND MANAGEMENT SUNDRY NOTICES AND REPORTS ON WELLS Do not use this form for proposals to drill or to deepen or reentry to a different reservoir. Use "APPLICATION FOR PERMITm" for such proposals SUBMIT IN TRIPLICATE -- 1. Type of Well pOil Gas Well IX] O Other Well 2. Name of Operator Union 0il Company of California (dba Unocal) 3. Address and Telephone No. P. O. Box 196247, .Anchora9e, Alaska 99519 I. Location of Well (Footage, Sec., T., R., M., or Survey Description) (907) 276-7600 Swanson River Unit Soldotna Creek Unit-- 17 wells 14 wells. FORM APPROVED Budget Bureau No. IO04-0135 Expires: March 31, i~3 5. Lease Designation and Serial No. 6. If Indian, Allottee or Tribe Name 7. If Unit or CA, Agreement Designation Swanson River/ Soldotna Creek Units 8. Well Name and No. 9. APl Well No. I0. Field and Pool, or Exploratory Area Swanson River Field I 1. County or Parish, State Kenai ~ Alaska CHECK APPROPRIATE BOX(s) TO INDICATE NATURE OF NOTICE, REPORT, OR OTHER DATA TYPE OF SUBMISSION TYPE OF ACTION [~ Notice of Intent F"'] Subsequent Report r'-] Fi~ Abandonment Notice r-]Abandonment F -] R~mpletion [~ Plugging Back O Casing Repair El Altering C~ing [~l Omer Tem. porari 1 y Ab.a.ndo. n r'"] C~nge of Plans O New Construction O Non-Routine Fracturing C~ Water Shut-Off Conversion to Injection F~ Dispose Water (Note: Report results of multiplecompletionon Well Completion or Recompletion Report and Log form.) Describe Proposed or Completed Operations (Clearly state all pertinent details, and give pertinent dates, including estimated date of starting any proposed work. If well is dlrectionaily drilled, give subsurface locations and measured and true vertical depths for all markers and zones pertinent to this work.)* As described in attached letter, Unocal requests that the following wells have a temporarily abandoned status for the twelve month period, April 1, 1993 to March 31, 1994' Swanson River Unit SCU 21-3 SCU 23B-3! SCU 13-4 SCU 21A-4 SCU 34-4 SCU 43A-4 SCU 33-5 SCU 21-8*/°~ SCU 243-8 SCU 341-8 SCU 13-9/ SCU 24A-9 SCU 34-9'~ SCU 14-34 Swanson River Unit SRU 212-10 SRU 14-15' SRU 23-15~ SRU 34-15 SRU 41A-15~ SRU 43A-15 SRU 432-15 SRU 14-22~ SRU 23-22 SRU 23-27 SRU 212-27~ SRU 34-28 SRU 43-28 SRU 14A-33 SRU 24-33~ SRU 32-33WD RECEIVED MAR 2 5 1993 · %r~r' Attachment No. 1 Swanson River Field ProPosed Temporarily Abandoned Wells: Total 31 Wells Twelve Month Period: April 1, 1993 to March 31, 1994 Shut-in Wells under Evaluation for Rate Potential P & An) Shallow Gas Potential and 'Hemlock Only' P & A SCU 13-4 SCU 21A-4 SCU 34-4 SCU 43A-4 SCU 33-5 SRU 341-8 SRU 34-28 SRU 43-28 SCU 32-33WD SCU 243-8 SCU 21-3 SRU 212-10 SRU 23-15 SRU 41A-15 SRU 14-22 SRU 23-22 SRU 212-27 SRU 331-27 SCU 14-34 SRU 23-27 SRU 14A-33 Shut-in Wells until the Field Blowdown · Hemlock Future Shallow Gas Producer Producers with the Hemlock Abandoned SCU 21-8" SCU 13-9 SCU 24A-9 SCU 34-9' SCU 23B-3' SRU 14-15 SRU 34-15 SRU 43A- 15 SRU 432-15 SRU 24-33(2~ 11 Wells 7 Wells 3 Wells 5 Wells 5 Wells :~ Does not include SRU 211-15. Scheduled full P & A in March-April, 1993 2~ Scheduled 'Hemlock Only' P & A in March-April, 1993. # High GOR wells that may be produced intermittently. RECEIVED MA 199 Alaska Oil.& Gas Cons. Commission Anchorage Attachment 2 Swanson River Field Wells with Temporarily Abandoned Status Change (Based on 1992's TA Status - December 27, 1991) Additions to 1993 Temporarily Abandoned Status · SCU 243-8: Shallow gas producer (Tyonek). Shut-in due to mechanical problems. Workover candidate. · SCU 21-3: Shut-in due to current high GOR. Mechanical problems. Removed from 1993 Temporarily Abandoned Status · SRU 21-22: Returned to production after flowline repair. · SRU 12A-4: · 'SRU 211-15 Returned to full time production in 1992. Scheduled for full P & A March-April, 1993. Waiting on. personnel and rig. RECEJVrr. D MAR 2 5 ~99;5 Alaska 0il & Gas Cons. Anchorage ARCO Alaska, Inc. ~ Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 Cook Inlet Engineering April 20, 1992 Mr. L. Smith Alaska Oil and Gas Conservation' Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Subject: Application for Sundry Approval for SRU 331-27: Mechanical Integrity Test and Step-Rate Test Dear Mr. Smith: Attached is an Application for Sundry Approval for SRU 331-27, a shut-in gas injector. The procedure outlines ARCO's plan to perform an "Unofficial" Mechanical Integrity Test followed by a Step-Rate Injectivity Test. These tests are being performed to determine the condition of the well and to determine its potential as a possible water injector. By converting the well to a water injector ARCO hopes to provide pressure support and increase the oil recovery from the offset producer SRU 21-27. If the well is found to be in good mechanical condition, meeting the current MIT requirements, we will then evaluate the well's injection capacity with a short term (less than 24 hours) step rate test. If the results of that test are favorable we will then submit a request for a change in status from a gas injector to a water injector. This would include repeating the MIT for witnessing by a State Inspector. If the work is unsUccessful the well will be scheduled for a full abandonment. The proposed operations plan and well schematic for SRU 331-27 are included for reference. If you require any further information in this regard, please do not hesitate to call Jim Zernell at 263-4107. Sincerely, J. C. Whan · Acting Regional Engineer RECEIVED TW:DRH:czm:0135 Attachments CC: Mr. W. Watson Mr. B. C. Dehn Marathon Oil Company UNOCAL Corporation APR 2 9 1992 Oil · Gas Cons. CornmisS~on ARCO Alaska, Int.. Is a Subsidiary of Atlantic Richfield Company STATE OF ALASKA ~ OIL,AND GAS ~RVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon Suspend Alter casing _ Repair well Change approved program _ Operation Shutdown_ Re-enter suspended well_ Plugging _ Time extension _ Stimulate ~ Pull tubing _ Variance _ Perforate __ Other X (Urloffical MIT & SRT) 2. Name of Operator ARCO Alaska. Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 4. Location of well at surface 40' FNL, 1730' FEL, Sec. 27, TSN, Rgw, SB&M At top of productive interval Straight Hole At effective depth At total depth 5. Type of Well: Development _ Exploratory _ Stratigraphic _ Service ..~ 6. Datum elevation (DF or KB) 206' KB 7. Unit or Property name Swanson River Unit 8. Well number SRU 331-27 9. Permit number feet 10. APl number 50-133-10156-00 11. Field/Pool Swanson River/Hemlock 12. Present well condition summary Total Depth: measured true vertical 12046' feet Plugs (measured) 12046' feet Effective depth: measured true vertical Casing Length Structural Conductor 2 2' Surface 1 4 90' Intermediate Production 11 620' Liner Perforation depth: measured 10975' feet Junk (measured) 10975' feet Size Cemented 20" Yes 1 3-3/8" Yes 7" Yes 10804'-10836'; 10849'-10878' true vertical 10804'-10836'; 10849'-10878' 13, Description summary of proposal _ · Tubing (size, grade, and measured depth 3-1/2" EUE to 10670' and 2-7/8" EUE 8 RD from 10670'- 10882'. Packers and SSSV (type and measured depth) Baker "FH" at 10776'; Baker "D" at 10846' Attachments 14. Estimated date for commencing operation June. 1992 16. If proposal was verbally approved Name of approver Measured depth True vertical depth 22' 22' 1490' 1490' 11 620' 1 1 620' RECEIVED APR 9 t992 Alaska 0ii & Gas Cons. c0mm'~ss'tot~ Anchorage Detailed operation program X BOP sketch _ Date approved I15. Status of well classification as: Oil __ Gas _ Suspended Service X (Gas Injection) 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ,/'7F~~_.~- Title Cook Inlet Re(:jional Engr. FOR COMMISS~DN USE ONLY Date Conditions of approval: Notify Commission so representative may witness IApproval Plug integrity_ BOP Test_ Location clearance m ~ /~c~ --,//~' Mechanical Integrity Test Subsequent form require 10-,/-/O~ ~,!'~!~ov~J Co y ORIGINAL SIGNED BY Approved by the order of the Commission !.,.0NNIE C. S~JIITH Commissioner Date -,~"-/~' ~,,~ Form 10-403 Rev 5/03/89 SUBMIT IN TRIPLICATE Unit Boundary SRI~ 21-27 , I · I I I i ~.--.,a ! · ! ' ' ' ' : ! } FalultBlock I I t I I I I I I RECE]V~ APR Y- ~ t~9~ Aiasl(a Oil A Gas Gon~. 'Anchorage Swanson River ~'~ield Structure Map Hemlock Formation /02--7~ -- ~ 2172 10695 , .. · -. . H4 H5 10804' i10836 i10878 15.40'- 22...20 ! - · · , WELL ~) Q,' (~./ ' .../-27 CASING A'I? T J~"'.O _~rAIL -- Tubing Hanger .40 3 PUP Jts. Top to Btm. 0.62',2.15; 4.03' 6.~JO 353 10,699.73'~10,732.52, X-OVZR 2~'~ x 3%" EUE 8rd Tbg. " I Jr. 2%" EUE 8rd Tbg. C~/.~O ~/~ ~D~L ~ I Wt. 2~" E~ 8rd.Tbg. i0, ~6.23 ' '~" ~'' ~' ~ ~ ~S" NIPPY, Position ~3 ~ ' ;'" "~ ~~.., "'" ' I ;~. 2~i'~ 8~ Tbg. 10,845.11 '_~ CA4CO ,Dn NI~ -' -;'.', ' 10~846'00~~ "Dh STOP ~U~ ~d S~L ~}~ r..2. iOZ7$ ~.P. '11 CO0 11058 11060' · ~.~-11185 Top of Plug © 11,450' 1! ;'7?0 ~ T.D. 12,0461 Alaska Oil.& Gas Cons. GemCssi~° Armhomge 10,677.53 -'i,lC 31.6c. 13.0C 30.71 6.~ 1.61:: 31.7~. 12..7~ 10.1 29.5~ Mr. L. Smith April 22, 1992 Page 2 TubingxCasing Annulus MIT SRU 331-27 Objective: To load TbgxPC and PCxSC and to verify the mechanical integrity of the TbgxPC prior to water injection Well data: A vertical well; SI gas injector; Open zones are H4 and H5 PC: Capacities: Top pkr. depth: Current Pressure: SC testing Pressure: Minimum ID: 3-1/2" to 10,700' MD; 2-?/$'to 10,845' MB 7"; N-80 and P-110; 26 and 29 lbs/ft to 11,620' MD; wall thickness = 0.317" 13-3/8"; 54.5 lbs/ft to 1490' MD TbfixPC= 0.0265 bbl/ft PCxSC= 0.1070 bbl/i~ 10,776' MD Tbg =2100 psi; PC =95 psi; SC =5 psi {as of 11/89) 2700 psi 2-3/$" tubing (Drift ID=1.995") @ 10,846' Procedure: . . . e . . . Load Tb~/xPC and PCxSC with lease water Install a two-pen recorder to monitor SC and PC pressures. Shoot fluid levels on TbgxPC and PCxSC. Calculate needed load volumes and prepare the fluid. If no loading is needed, proceed to step 10. Monitor Tbg, PC and SC pressures throughout the job. Hold a safety meeting. RU choke and gas buster to SC, as needed. Blow down SC pressure without allowing fluid production. Hook up the pump truck to SC and pressure test lines to 4500 psi. RECEIVED APR 9 992 Oil & Gas ~Jons, ~ommissi~ ~chorage Mr. L. Smith April 22, 1992 Page 4 Objective: Well data: Step-Rate Test SRU 331-27 To establish the injection rate versus pressure relationship A vertical PC: Capacities: Top pkr. depth: Current Pressure: Surface Injection P: Minimum ID: Procedure: . . . . . . . . . 10. well; SI gas injector; Open zones: H4 and H5 3-1/2' to 10,700' MD; 2-?/8" to 10,845' MD 7"; N-80 and P-110; 26 and 29 lbs/~ to 11,620' MD; wall thickness = 0.317' 13-3/8"; 54.5 lbs//t to 1490' MD TbgxPC= 0.0265 bbl/ft PCxSC= 0.1070 bbl/ft 10,776' MD Tbg =2100 psi; PC =95 psi; SC =5 psi (asof 11/89) 3,000 ps~ 2-3/8" tubing (Drift ID= 1.995") @ 10,846' Hold a safety meeting and ensure that fire extinguishers are on location. Verify the accuracy of volume and rate meters. Rig up Slicldine. Pressure test the lubricator to 3,500 psi. RIH and pull a 2-1/2" 'PS' plug at 10,783' MD and record the WLM of the profile. RIH and make 1-1/2" gauge run to tag fill. Tie-in to the 'S' nipple position #3 depth, 10,783' MD (WLM in Step 5). NOTE: The last gauge run was with a 2-1/4" gauge to 10,860' MD on 2/86. Rig up a pump truck to inject lease water. NOTE: Filter all lease water to be pumped downhole. Pressure test the line to 3,500 psi. Fill the tubing with filtered lease water (- 65 bbls). Bleed off any gas left in the tubing. RECE JVF_g APR Alaska Oil & Gas Cons. Anchorage Mr. L. Smith April 22, 1992 Page 5 11. 12. 13. 14. 15. Step-Rate Test SRU 331-27 (cont'd) Begin injection for SRT. Record the injection rate and surface injection pressure in 100 psi increments, starting at the surface injection pressure of 200 psi. NOTE: A data collecting table and graphing paper are included in Attachments 2 and 3, respectively. Stablize the well at each step. Increase the surface injection pressure until it reaches a maximum of 3,000 psi. Plot the injection rate versus pressure. Shut-in the well. RECEIVED APR 2 9 '~992 :Oil :& 6as Cons. Anchorage Mr. J. A. Dy gas Page 2 December 27, 1991 Shut-in wells until field blowdown, including: 4. Hemlock producers, and 5. wells with future shallow gas potential in which the Hemlock has been abandoned. The fifth category shown above is a new addition to this year's TA listing. This grouping is for the wells in which the Hemlock has been abandoned but the wellbore is being maintained for possible future shallow gas production. Four wells from last ye,ar's TA list were moved into this category. Attachment 2 gives a brief explanation for each well that has been added to or removed from the 1991 Temporarily Abandoned List (Ref: our letter of 12/28/90). Eight wells, SCU 12A-4, SCU 21-8, SCU 23B-3, SCU 43A-4, SCU 13-9, SRU 212-10, SRU 21-22 and SRU 212-27, have been added while two wells, SRU 21-15 and SRU 314-27, have been removed from the previous TA List. Attachment 3 is a list of shut-in wells that are not included in the '92 TA listing. Two of the wells mentioned above, SRU 21-15 and SRU 314-27, are not included because they are scheduled for P & A in the first quarter of 1992. This work is being done as part of the '91-'92 Swanson River Plan of Development. Also included in Attachment 3 is SCU 43-4WD, a standby water disposal well which is only used seasonally. If you have any questions concerning this Sundry Notice request, please call Hyeh- Yeon Hoffer at 265-1355 or Jim Zernell at 263-4.107. Sincerely, J. C. W inn Acting Regional Engineer JTZ:jlg:0025 Attachment CC:. L. C. Smith, Chairman AOGCC A. R. Kukla, Marathon Oil Company B. C. Dehn, UNOCAL Corporation R£CE V£D Alaska Oil & ~as Cons. Attachment 1 Swanson River Field Proposed Temporarily Abandon Wells: Total 32 Wells Shut-in Wells under Evaluation for I I Shallow Gas Potential Rate Potential P & A and 'Hemlock Only' P & A SCU 12A-4 SRU 212-10 SCU 14-34 SCU 13-4 SRU 211-15 SRU 23-27 SCU 21A-4 SRU 23-15 SRU 14A-33 SCU 34-4 SRU 41A-15 SCU 43A-4 SRU 14-22 SCU 33-5 SRU 23-22 SCU 341-8 SRU 212-27 SRU 21-22 SRU 331-27 SRU 34-28 SRU 24-33 SRU 43-28 SRU 32-33WD · 11 Wells 9 Well~ 3 Wells Shut-in Wells until the Field Blowdown Future Shallow Gas Producer Hemlock Producers with the Hemlock Abandoned i:~:i:i:i:i:i:i:i:i:i:i:i:i:i:i:i::.:i:i:i:i:i:i:~:i:i:!:i:i:!:!:i:!:!:i:i:i:i:i:i:~:i:~i:!:i:i:i:i:!:i:i:i:!:i:i:i:i:i::;i:!:i:i:i:i::;i:i:i:i:~:i:i:i:.~i:i:~:i:i:!~:i:ii:i:.~:i:i:i:i:i:~:i~.~i:i::;i:~:i:i:!:i:i:i::;i:~:i:~:i:i..~:i:!:i:i:i:~:~:i:i:i:i:i:~i:i:i:::~::~:i:~:i::..i:si SCU 21-8 * SCU 13-9 SCU 24A-9 SCU 34-9 SCU 23B-3 * SRU 14-15 SRU 34-15 SRU 43A-15 SRU 432-15 5 Wells 4 Wells * -High GOR wells that may be produced intermittently. For. Temporarily Abandonment Sundry 12/27/91. Attachment 2 RECEIVED Swanson River Field Wells with Temporarily Abandoned Status Change (Based on 1991's TA Status; our letter 12/28/90) DEC ,) 1 199t Alaska Oil & Gas Cons. Commiss. Anchorage Added to 1992 Temporarily Abandoned Status: · SCU 23B-3 & · SCU 21-8: SCU 12A-4: High GOR wells, maYbe produced intermittently, otherwise shut-in until blowdown. · High GOR well, may be. produce intermittently, This well is also being considered as a workover . candidate. · · SCU 43A-4: Shut-in due to mechanical problems. Also being considered as a workover candidate for shallow gas. · SCU 13-9: High GOR well, shut-in until field blowdown. · .SRU 212-10 & · SRU 212-27: High water rate shallow fuel gas well, currently not economic to produce based on current fuel gas needs. · SRU 21'22: Well currently shut-in due to problems with the towline. Well will be returned to production when repairs have been completed. Removed from 1991 Temporarily Abandoned Status · SRU 21-15 & · SRU 314-27: Wells are scheduled for full P & A in 1st Quarter 1992 as part of the '91-'92 SRF Plan of Development. Note: 'Hemlock Only' abandonments were performed on SRU 14-15, SRU 34-15, SRU 43A-15 and SRU 432-15. These wellbores are being maintained for their future shallow gas potential and remain on the TA List for 1992. Aff~achmgnt ~ Swanson River Field Shut-in Wells not on the 1992 TA Status List Wells with planned upcoming · SRU 21-15 & · SRU 314-27: work: Wells are scheduled for P & A in first quarter 1992. Wells that are used seasonally · SCU 43-4WD: This water/mud disposal well is a standby well and is only used on an 'as needed' basis. RECEIVED DEC 3 1 1991 Alaska Oil & Gas Cons. uummissios, Anchoraoe ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 Cook Inlet Engineering December 27, 1991 Mr. J. A. Dygas Chief Branch of Lease Operations (AK-984) Bureau of Land Management 222 West 7th Avenue Post Office BoX 13 Anchorage, AK 99513-7599 Subject: 1992 Sundry_ Notice Request for TA Wells in Swlm~Qn River Field Dear Mr. Dygas: Attached is a Sundry Notice, requesting approval to temporarily abandon (TA) 32 wells in the Swanson River Field for a period of 12 months. This Sundry Notice is being submitted to comply with Chapter II, Section 3162.3-4, paragraph (c) of the Bureau'of Land Management Regulations. All 32 wells are expected "to be shut-in for a period of at least 30 days during 1992. Several information sheets are attached with this Sundry Notice request. Attachment 1 lists the proposed TA wells and separates them into the following five categories: Shut-in wells under evaluation for: . rate potential, permanent abandonment (P & A), and shallow gas sand potential and 'Hemlock Only ' abandonment. RECEIVED DEC ~ 1 199t Alaska Oil & Gas cons..C~mmissio" Anchorage Form P--3 ~ S~brflit "Intentions" in Triplicate ~ ~e~.- .. _~/_~ . STATE O/: ALASKA is. API NU~U¢~ ¢OD~. OIL AND GAS CONSERVATIO. N COMMITTEE, ' J l 22E~ ~,1' SUNDRY NOTICES AND REPORTS ON WELLS (Do not use this form for proposals to drill or to deepen Use "A.P.P-LICATION 'F. OR ~'EH~i'i'-L.'' '/or such'pr~o~osal$.) A-02840~ ~ELL Gas injector "'~'i NAME OF OPFA~ATOR S. UNIT, F~d~_M OR LEASE Standard 0il Company of California~ W0I .~,,~n.~m_n_ River -~-~-i~v ..... '~'. ^DD~SS OF O~ATO~ ~. W~L NO. ~,--~--_ __ P.O. BOX 7-839, Anchorage, Alaska 99510 SRU 331-27 ~'-'~c~-- 4. LOCATION OF WELL 10. FLEI_~ A~ID POOL, OR WILDCAT At surface 1730' West and 40' South of NE corner of Swanson River Sec 27, T8N, R9W, SB&M u. s~.c., T., ~., ~.. (~O~rO~ ~O~-~- - -- _ ._ ~ ....... ' OBJECTIVE) - -- Sec 27, TSN, Rgw, SB&M 13. ELEVATIONS (Show whether DF. RT, GH, etc. 12, PERIVIIT NO. 272' ~B Check Appropriate Box To I,ndi'c~te Nature of N~ti'ce, Re, tort, or Other D~t~ NOTICE OF INTENTION TO: TEST wATER SHUT-OFF t I PULL OR ALTER CASING FRACTURE TREAT -- MULTIPLE COMPI,ETE SHOOT OR ACIDIZE __ ABANDONS REPAIR WELL, CHANOE PLANS RUBSEQUENT REPORT OF: WATER SItUT-OFF REPAIRING WELL FRACTURE TREATMENT ALTERING CASING SHOOTING OR ACIDIZING · ABANDONMEKT* (Other) Injection (NOTE: Report results of multiple completion on Well ~Other) Completion or Reeompletion Report and Log form.) DESCRIBE PROPOSED OR COMPLETED OPERATIONS (Clearly state all pertinent details, and give pertinent dates, including estimated date of starting any propOsed work. Resumed injection on 7/7/72. Currently injecting at 14, 630 B/D and 5470 psi. (TbII space for State office use) APPROVED BY CONDITIONS OF APPROVAL, IF ANY: TITLE DATE See Instructions On Reverse Side WELL RECORD INVENTORY Field: Locati on _ . Swanson River Unit TSN-R9W, _Sec. 27.,...S.M. Opa~ato~ & Well Name: Standard Oil Co. . . , , Unit #331-27_ _ No. Pages l. Drilling Pemtt: 2. Survey Plat: 3. Monthly Reports (P-3): 4.. Completion Report (P'7):I 5. Well Htsto~,: 6. Other: 7. Mi s ce ) 1 aneous: 8. Deviation Survey(s): TOtal Pages: 9. Well Logs: .(.1.) ~ .... (2) EL (4) CBND (5) _ i6) (7) (8) (.lO) . (S(~I1.1II7' I.% TR1PI. I(J.4TI,:) UNITED STATES DEPARTMENT OF THE INTERIOR GEOLOGICAL SURVEY SUNDRY NOTICES AND REPORTS ON WELLS NOTICE OF INTENTION TO DPt[ L NOTICE OF INTEN]t?N T(; C~{n';(SE ~: .~.',: NOTICE OF INT[NTIt~N TO TES: ,',,%1~ NOTICE OF IN!ENTiON TO ~E OqlLL O~{ ~EF>Aif.~ Y,'FLL NOIICE OF INFE:h-Ib",tq ?O NOTICE OF INTENTION '[() PULL ON ~d F~R C~SING NOTICE OF INTENTION '[O ADANDO~4 N~. of Intention to El~i~te Water SUBSEQUENT REFORF OF '~,.',,I-£R SHUF-OFc SUBSEQU[NI RF:'OR? )F S,i(;O~'I~;G OR ACID~ZING SUSSEGUEN1 [~,£;'C:RT ~;~ ALTE:~iNG CASING SUi?SFFOL'ENT REPOF:T C, RE-DRILLING OR RE'PgIR SUBSEQUENT t~EPG~ ,.)[ gB,,~NDONMLNT SUPPLEMENTARY . 19 Well No. 31-27 is h,caLe,l 40 ft. £rom (N' Ene and 1730 ft. From 'E , line of sec. ._~.~. ~7 _ ..~SN a~ ._ ~a~~ ()~ ~,.,.. :,::4 N,,.) (Twp.) ~ I~:,, .:~. (M,,~ :.~.~;~, ~anson River Ke~i l~s~ The elevation of the ct,,rl'ick floor al)ore ,,ca level is 272 ft. DETA ILS "DF WORK Please refer to attached Program,, Company Standard Oil Company of California, Western .Olme. ra..t, io.n.s~ Inc. Address Po O. Box 7-839 Anchorage, Alaska t'or-p, 1 P - ? SUBMIT IN D .~ICATE* STATE OF ALASKA ',see other in- st ructions on reve:-.~e side OIL AND GAS CONSERVATION COSMITTEE ii WELL COMPLETION OR RECOMPLETION REPORT AND LOG* la. TYPE 0F WELL: on, ~ u,s ~ ~ O~her ~VELL WELL ~ DRY b. TYPE OF COMPLE~ON: WELI. OVER ~ KN ~ACK gESVR. Other 2. NAME OF OPERATO~ 3. ADDRESS OF OPERATOR 4. L0C~rmN OF WELL (Report location clearl~l and in accordance with a~y State requiremetzt~)* At surface At top prod. interval reported below At total depth TOTAL DEP'rH, NLD & TVD[19. PLUG, B~CK MD & TVD~I0. IF i~ULT1PLE CO1ViPL., 21. ! HOW 1VIANY' ROTAR¥ TOOLS PRODUCING INTERVAL(S), OF THIS CO.MPLETIOAI~TO,P, BOTTOM, NAME (MD AND TV'D)* 24. TYPE ELECTRIC AND OTHER LoGs RUN 5. API NLrMER/CAL CODE 6. LEASE DESIGNA.~iON A.i'qD SERIAL NO. 7. IF INDIA.N, AI.,L,O~ OR TRIBE NA. ME 8. UNIT,FARM OR LEASE NA/%IE 9. WELL NO. 10. FIELD A2%rD POOL, OR WILDCA. T 11. SEC., T., R., M., (BOTTOM HOLE OBJECTIVE) 12. PER1VIIT NO. ! 16. ELEVATIONS (DF, RKB RT, GR, ETC)*ll7. ELEV. CASINGHEAD INTERVALS DRILLED BY CABLE TOOLS 23. ~,VAS D!RECTIONA. L SURVEY il/lADE ,i CASING RECORD (Report all strings set in well) HOLE SIZE , 28. PERFORATIONS OPEN TO PRODUCTION (interval, size and number) IO, Sff- M?J ., II I I 30, PRODUCTI ON CEMLNTiNG RECO}ID 29. ii~[OUNT PULLED 27. TUBING REC,OI~uD ACID, S~!OT, F:I.ACTURE, C~,[ENT SQUE2Z~, ETC. DFk~TIi i~TTF_~V.~., (MD) I£~A'IOUNf i'~ND }lIND OF MATE?J. AL USED DATE FIRST Pt~ODUCTION ! I:~ODUCT1ON MEI[{OD (Flowit~g, gas lif[, pumping--size and type of pump) HOURS %~ES.TED ' [CI-!OI-[E SIZE IPEOD'N DAT~ 0F T~ST, OI~L. ~¥W, TUBING CASIYqG PRESSURE [CALC~T~ 'OI~BBL. GAS--~XCF. :: i 31. DISPOSiTiON OF GAS (801d, used for fuel, vented, etc.) 32. LIST OF ATTACHMENTS ] V/ELL STATUS (Producing or ~nuL-in) G.%S--2ViCF. WATER--BBL. [ GAS-OIL ILkTIO I 1 WA~BBL. [ OIL GRAVITY-~I (CO~R.) 1 TEST WITNESSED BY 33. I hereby certify that the foregoing and attached information is complete and correct as determined from all-available records *(See Instructions and Spaces [or Additional Data on Reverse Side) SNOIJ.:)nuJ. SNI Cc~amen~ drIll~ eT~ratiome &t I:00 AR 11-10-57. ~ilie~ hole to 18-~/S. o' - .~, pea ~ra~el and clay ~v~r 17, 1957: Ran electmlc log a~ 3933'. ~ 8~" hole to 10-5./8" 35~3' - 3933' a~i ~rilled 10-~/~ Mole 3933' - ~lo'. ~ea lOo~/8~ ~ole ~ ~i~ 8~, ~o~e ~ ~e~ 7-~/~ ~e ~mO' ~ ~3'. o~~ 8~- ~i, ~o io-5/8" ~OlO, - ~i8o,. 3933' ~i~0' November 25, 1997: ~.S,T. ~3iT' - ~376 36o' WoC., 5/16" bean~ 2 hour tea%. There was a li~h% steady ~I~ '~p~'~t te~"~ ~o~ a net fl.u~ rise of 1~' test. ~!s ~ ~l~ p~ed wich Drilie~ az~ cored 7-5/8" bole k376' - ~376' k well sorted, roumte~ to ~~, ~, fe~, o~ P~n eleetmtc l~ ~m %53~', mX~eilper re¢ordim~ ~531' - 3500' am~ ~ k 41]~ lew~li. ~eMd 7-9/0" ho~, to mO-~/8" k303' ' ~', V53~' %TIO' WTIO' firm-friable. Occa~lomal coal fra~Imta. ~.. :rem~mi mud wei4;h% frum ~l;/~.f. to 96g;/¢.r. vhile ~xiZltm~: .% 9780' to ~ the ta- :a~ em%Frustum ~f ~m~ l~ ~tio~ with high head water. 55~' 5~90' 6569' 896o' 896o' 10,06~' 10,069' 10,01]' ~ and Ib~le ~ e~al and re.hale $hale, coal and me~m~ ~t~d da?lLlIed depth h~ ~ HIB2'OR¥ December 28, 1957: Ban electric lo~ from 10~073', took iQ dip~eter levels. Drilled I0-~/8" hci= 10,073' - I0, i~5'. 10,073' 10,186' ~d aud s~ale ~a~ ama ahale Care ~10 - Recovered ~ O~, c~e ~~ ~h 7' ~'. ~i~!e, ~- 2' O~ ~_, fine ~~, f~, ~i~le, 1~ 1~ c~~te ~bblem to I" f~heme local mtrea~ ~tt~ ~ t~ht with 7e 41~. ~y ~, d~fic~t~ fr~, ~ ~ - ~o~ 31' a~i~lt~ fr~le, ~ ~t~. Faint. ~o1~ 10~ ~1 ~, 1~ bra, 1~ 3' to 6~ co~l~ra~ has ~r~ b .....~ '-'~'n o.i,i. ~ed~-~8 fsir to OJi. Co~~r~t~. v~:-cc, lor~ ~~. F~r~, firable ~c~ ~l~rat, ble~m ~k ~ oil. ~r ~ir~ ~/5~I.0* dipm. ~ oil ~. ~ ~ ,~ar, ~k a~er cut. .Jaamary 7, 1958: Ban electric log from !0.,~', p~o%oc, ii.momctar ~u.~y ~. t~k ~ ~I~~ t~ve.l~ G~ ~" 10,~' ~,~ ' ~ ~ co~la.r, lore_ ~ ~ ]b~iMer ga~a Bbd4tm f~- ca~ln~ equipment. _. 80' 11,856' cr fluare~ce~'e wi~h thinly Imt. erb~ s~Ze a~ above, 7' 81~!e d~k !.rtwn.-grey:, $i'~'~* ~" , . .~.~..~ silty a ml. caceo~, ~'d wit?', cccz~on t&la streaks p)mite ~ b~,t~ 2', C~e ~ - ~,:,?,~re~ ~5~ ~' ~e~ brc;va~ey~ ~ll. ght.Ly ~lty ~ ~cace~, ~ii.~ly' t!~ s~e ~!ick.~ m.;.rface~ ~'t. 56' ~'~ ver~lc~i; very c~c~r~..,~., mlca.cec~:..~, very ~l~t~ got.~i f!u~e~e~e, t ...... ~ ::'ut, no visible s~.;n~ no distribute4 t.h:'~ ~:d~'%o~e a~ ~ever~i 'thin 11,884 11,910' !I~, 9.31' 19' ~..~, ..~. ..... ~,. ~t~ ~ I.i,~7~'; one di.~ ...... 9~ .C~ ~ fat~ ~:',:~ ~'~ . r'~-, ~a.,..... .,;z - c,'.., ......... .~ ,;%" .... Core j~6 -Re.:,:we~ed ~ey clay ~:e, bec~l~ ' c~c~: ~o ~c~dy fr~t~e in the bot~ g~'. A f~ ~hin ler~es ~d. ~8 of ~ry f~e ~mln~ t~t ~eenl. mh ~ey ~mtone. ~o visible dip. Core ~ to break at Il~ - ]9'. Aver~ l~' - ~or. C~'e ~ - Recovered ~.~' ~t (?) fr~mta; ae~ very f~, ~ ~i~. ~or ~l~ 15e - ~e om allty a~. C~ ~ - R~er~ I1' ~r~ thin, ~ite, calc!te-fl~ ~e ~9 - ~cover~ 8' ~~~hlc roc~ of d~bt~l cl~tficati~, of ~k ~ey tc ~eeuimh a~ie ~ a~iey a~ato~ which con~ ~ch i.~e~a debrie - ~~r ~h~bol~ n~'~ "~:~. a]:l. very t:~te, no reb~ 15, Ran ele~lc lm~ at 12,0~6', took 2 dtpmeter level, t. Ran in with 6" bi~, foumd top of Dlug at I1,~50'~ tested full pum~, ok. Pres~ teated plu6 and casing w!t.h 1000 psi for 30 minutem~ ok. Fulled out, laid dcw~ drill pipe. removed B.O.P.E. Luatalled X-~m~ tree. Neutron collar locker log. ~ecor~e~ ~l, ~7' to sur~ce. ~a~ baek i~ With Schlumberger Je~ ~for~tor. Perforated E-log inter~l 11,!8~'~ ~, 1.9~' v~'t~ l~ Je~s/fcot ~ 8, Ran ~ ~ of E-~g i~e~ ~,~'-~,1~' ~ ~~n ~~c tes~r. ~~ ~ ~ s.~t~ ~. ~ tm~ of oil. ~tsi~ ~ 7565 15~0 1~5 ~0 7515 ~aa in with ~er ~Iezt control ual~ aat stimler sub. ~ ~ ~~ ~~r' ~t 11,16~' ~ 2-7/8" ~~ ~ ~~s. P~~ ~,~ on ~~r, ~'" o.k. A'~t~d ~ b~ ~ fo~tl~ ~ ~. ~d ~t ~ b~ ~. collar i~~r f~ ~ of c~t ~ at ~,~'. .,. . . AM~~~b~~e~i~~ ~ b~w~r ~a. ~e~ ~t b~for ~ ~] ~m. ~r ~oa ~ s~ ~ 1:~, oil ~ ~~ ia 2 ~, 35 ~a, Section 22, T. 8 N..t R. ~ W., Sewar~ B. & M~ STAmm or ' Pa e (DecOr 10, 1958 continue~) Oil flowed for 2 hours. Very 2ittle g~s. Last w~ll sample ln~icat~ following: 28.7 gravity, cut 7~ water. Set Baker Mo~el K bridge plug at ll, OO0'. Pressumes: IH IF FF FSI]? Outside BT 7650 12~0 3750 5675 Imside BT 7610 1160 3720 5660 Jet perforate~ 1~ . 1/2" holes at !0,795'. ~ water shutoff at 10, Y95' with ~lLi- burton h~c tester. Eau 3000' water cushion. Set packer at 10,765'. Opemed tester at ~:39 A.M. w~th faint blow for 41 minutes then dead for remainder of test. .Tester opemed 1-1/2 hours. ~ecovered 120 feet met rise of drilling fluid. Charts indicated good test. Ran drill pi~e and conditioned mud at 10,960'. Jet perforated at 10,880', E-log depth, with ~jets. Ran water s~utoff res% at 10,880' with Nalli~~u hydraulic tester. ~u 2970' of water cushion. Se% packer at 10,850'. Opened tester at ~:20 A.~. with faint blow for entire test. :fester opened 2-1/2 hours. I hour fiual ~hut-ino Recovere~ 180' net rise (90' oil and 90' dri ~lliug fluid). Charts indicate~ good test. Pressures: IH iF FF FBI FH Outsl~e recorder ~TS20 1~30 1~80 5320 7565 drill pipe and d~Illed out Baker Model K bridge plug and c/o casiug to ll, ll3'. ecem er z3, ~, .m__,m~m em. - '~-~: -~-~ __ ~xe~ ~ bar~ of b~ck ~c in t~ fo~o~ ~tio: 81 lbs. b~c~ ~, 33 ~s. ~esel o~i, 2 ~. -~ter, ! lb. ~c~ ~,,. Spo%~ 20 bbl,. of b~ ~c ~x at ~,073'. ~led ~ pipe. ~ i~ ~ ~~~er Jet ~, stud at 1700'. R~ In D.P~ ~n ~ to l~' ~ ~r~~d ~d. ~ve~ 2 D.P. ~b~r p~tec~rs. ~~ D.P. ~ ~r j~ ~'t~er. S~pped at 970C'. ~ed out j~ catc~r. Cut ~ ~ at ~' ~~se of 2 ~baskets in %~ ~. ~ ~ne abovu j~ cat,er sho~ ~t~er s~pped lu B~ ~c-gel ~ ~n~ct ~~ ~ e~~ ~_sc~s.. ~ D.P. ~th 6" bit ~ ~,~3', ~rcu~ted out B~ ~c ~. Section 22, T. 8 N.~ R. ~. W., Seward B. & M. December 1~ 1958 Ill I 3__ I $~1 ~m e ~ .......................................... ........ Jet perforate6 with four 1/2" holes per foot B-log intervals 10,804' -' and 10,8~9' - 10~.878'. Ram Baker ~ scraper. Scraped casing. Circulated and conditioned mud. Gas and oil on ditch 35 mlnmtes circaulating. Laid down 2-7/8" drill pipe. Made up 4000' J-55 2-1/2" tubing, 6800' N-80 2-1/2" tubing. Oecem e? 16, 1958 .......... Pulled ~bi~ ~ ~ J~ ~sher on ~ ~ ~ch s~ppe~ at 7100'. R~ open 'e~ t~i~ ~ ~ack seuttled ~ ~n~~ ~le ~ ~,~'. ~ J~ pus~r to ~,0~' · December 17, 1958 Set Baker Model D production packer at 10,902'. Ban tubing with 2 Joints of 2" perforated tubing on bottom then 2 Joints of 2" ble~xk tubing, then Baker Model D adapter sub au~ Baker tubing locater seal asse~mb~, one five foot pup joint, then 2~z" tubing Oamco lan~Ling nipple, ~ ~ints of ~" perforated tubing, then 2 Joints of b!_-_~ 2~" tubing, them ~k~iberson KV 30 production packer. Set KV 30 packer a~ 10,762' with bottom Joint of 2" ~mbing hanging at 11,0~3'. 2~" tu~ing from KV 30 to surface. ~ter in tubing. 01osed by-pa~s. ~ell ~o~ ~t f]~. ~bbe~ in ~ta~s to bSO0 _Dec ~ember ~19, 1958 Well began flowing at 6:15 A.M. Flowed well at ~pproxlmately 300 B/D rate for 17 hours. Production believed to be frcm~ lower perforated interv~ only. m~~mmm-m m-~ ~ m m~ m m-i~i mm immm m m m mm mm S mm mil ee mm m m mml m m m mmme mm mmmm ~ s m m mm .Ii m mmm m mm ~ ~ ~ m mmm mlm m m ~ ~en e~ tubl~ ~ 10,890' ~ con~tion~ ~d to 86 per. ~ott~ ~ ~rrels of low ~ter loss oil ~lsion ~d on ~ttom. ~-jet pe~o~ted E-~g inte~,~s 10,~9-10,878 ~ 10,~-10,8~. ~~ ~i~ tester ~ test pe~s bergen 10,~' -10,878' · P4~n DST ~4 of perforate~ intervals 10, 80[-1~, 836 and !0,~9-10,878 usi~ ~bu~on ~~c tester on ~" tubi~. ~ene~ ~ster at ~:10 A.M. ~m to st~ blow OIL ~0. 0F ~~NIA- ' O~TO~ '" (December 22, 1~ continued) then dead after ten ninutes. Reset ~acker a% 11:~0 A.M. Intermittent light blow ~!u~ier ~f test. Clcse~ tester at ~:00 P.~. for 1 hour fiz~l shut-.~n. Ran ~000' ~ater cushion. -F~t ~ckmr at 10,750'. ~cevere~ 3700' net rise - oil. Ou~si~e reco.w~er tn~icatea p!uggi. ~ of tester ~erformted t~il. Pressur~: IX 1~ , IF FF FSIP Zna~de Reeorder 6~80 6g~0 ~390 3~35 56~o Back scut%le~ aad eemditio~ed ~ at 10,~1'. Co~l~~~ ~~t ~d o~er ~st cir~t~om ~te~l sho~ ~ ~r. ~s ~~al ~ib~ ente~ ~ tu~. ~~ ~ubi~ ~ 1 Joint of 2'" ~ ~tt~ t~.,~~ ~1 D ~~r ]:30 A.M. ~~ ~ to 36/~. ~t in ~bi~ p~s~ 1~ psi, f~n~ p~ss~ ~ psi. ~ 5:~ ~ 7:~A.M. ~at est~~ ~ to 2~ ~H. Shut in at 12:0~ nooa Muiting cou~letioa of ~rodu~on fa~i~ties ~o oil coul~ Be turned t~ tanks for an accurate g~uge. Flow Test - ~ell opened &~ 6:30 A.M. SMut in ~r~ssure 1720. 8:30 A.M. - 1~. -re l~_~l./O, 2~./6~ beaa, '~ 380, estim~ p,s 200-250 ~F ~er day, 9:~ A.M. - ~ ~3/0, ~, ~, ~ 3~, ~ ~-2~ D~ t~~ut ~t. ~o:~ A.Z. - ~ ~/0, ~ 3~0, ~ ~., ~t S%. 0.~ ~r, 0.~ ~i~. ~:~ A.~. ~ ~2/0 m~, ~ ~, ~ ~, ~t 0.7%- o.]% ~r, 0.~ ~:30 P.M, - ~ ~/0~ ~ ~, ~ ~, ~ 0.~ ~ ~r, ~ t~ce~ ~:~ ~.M. - ~~ m~ for 8 ~ . ~/o m~, ~/6~ ~, ~ ~, ~t o.~. 0.~ ~r, 0.~ ~i~~ t~, ~ty ~.6 at ~2 ~ee. ~ell shut in at 2:~0 P.M. ~hut ia tubing ~rems~am~ 1700 killed well. Section 2P, T. 8 M., R. 9 k'_-~ Seward B. & ~. sz~m~ oz~ co' o~ ~m~ ~ ~~- 810 Corrected gravity averages 30.8 at 60°. l~°rm P-"~ Subralt "Intentions" in 'lhriplicat~e STATE OF A~SKA ~..X~t N~mc.m cons OIL AND GAS CONSERVATION COMMI~EE ' J? ?NG SUNDRY NOTICES AND REPORTS ON WEL~ J Uze ".:'~PLICA'I'ION FOR P~CMIT--" for such proposals.) A-- 0 2 8 4 0 6 1. ~. IF ~i~N, a'~ OR T~B] N~i~ OIL ~,~ ~ ~'~ ~ If GEOL S~andard 0~ Compan~ o~ Ca~ornSa, W.O.]. S~anson R~rJ 3 GEOL~J s. ~nn~ss or o~s~.~o~ ' ~. w~ so. j ~Ev P. O. BOx T-B39, Ancho~ge~ ~ask~ 995~0 SRU 3~-2~ J DRAFT ~t surface /. ~ S~S O~ R~V ~NF~R: ~30~ ~eS¢ an8 40* Sou~h ~om NE corner of "n. ssc.,~.,s.,>z.,(so~om~o~ O~IVE) Section 27, TSN, Rgw, SB&M '. Section 27 , _TSN, Rgw, 1~. ELEVATIONS (Show whether DF. KT, O~, etc. " IM. P~%IiT ~'O. !CB :289 ' Check Appropriate Box To Indicate Nature of Notice, Re oort, or Other Dato TEST WATER SItUT-OFF PULL OR ALTER CA~ING - FRACTUHE TRKAT ~ MELTIPL~ COMPLETE 8HOOT OR AC~DI:E ABANDONS REPAIR ~"~LL CHANO~ PLANS ~Other~._Co~ve..r~ to cas injector :- mUBIIEQUIJNTREPORT OF: fRACTURE TREAT~ZENT ' '' ALTEalNO CASINO SHOOTING OR ACIDIZING J J ABANDONMENT" - (Other) ~NoTZ: Report result~ of multiple eomple~lon on Completion or RecomDletlon Report and L~ form.) 15. I)£SCRIBE PROPOSED OR COMPLETED OPERATION& (Clearly state all pertinent details, and give pertinent dates Including estimated date of starting any l~ropo~ed work. ' Attached is a proposal to convert SRU 31-27, a shut-in oil well, to a gas injection well. These conversions are necessary to accomodate a new 3400 hp compressor currently being .installed. I? .: .i .~ '?: :'. - ' . . DIVISIONOF_ OIL AND GAS -_ _~ ANCHO~AGB ........... : . 16. I hereby cert4~y t~,~ .he)~r.eg0i~:;.~=,~.~_0r .~t~_ ..... ./ ./ / CONDITtONg OF APt R0'VAL, ,%.e ltnstr,~ctions On Reverse Side DATE WELL SRU 31-27 SWANSON RIVER FIELD MARCH 4, 1971 REMEDIA{. PROGRAM PROPOSED WORK: PRESENT STATUS: Convert a shut-in oil well to a gas injection well. Total De.Dth: 12 , 046 ' Plugs: 11,720'-11,450' and 11,167'- 11,123' cement. Cast iron B.P. at 11,000' and 10,975' Casing: 20" 13 ?- 3/8" conductor pipe cemented at 22' 54.5~ J-55 cemented at 1490' 26~ & 29# P-il0 & N-80 cemented at 11,620' Casing Detail Bottom 924' Next 2504' Next 6020' Next 1100' Top 1072' 11,620' Perforations (11,620'-10,696') (10,696'- 8,192') (8,192'- 2,172') (2,172'- 1,072') (1,072'- 0') 29# P-110 'LT&C 2.9~ N-80 LT&C 29~ N-80 LT&C ~- '~'' 29# P-il0 LT&C DIVISION OF OIL AND GAS ANCHORAGE WSO at 10,795' and 10,880' 4 - jet holes per foot at intervals: 11,185'-11,195';11,038'-11,060';10,849'-10,878' and 10,804'-10,836'. Reper~orated with 2-1/2" crack jet holes per foot 10,849'-10,878' and 10,804'-10,836'. Tubing: As per attached "Casing and Tubing Detail" dated 5-13-63. Elevation: Datum is 15' above ground level at original K.B. elevation of 272'. Junk and Condition of Casinc: No _junk or bad pipe reported. BOPE Considerations: Static formation Dressur.e is 4900 ~si at ~z. pp .. ~ depth of 10,842'. Class III BOPE %;ili be utilized. SRU 31-27 REMEDIAL PROGRAM MARCII 4, 1971 PROGRAM: MoYe in contract rig and mix 71-72 pcf mud. (Provides a hydro- static pressure of 5325-5400 psig at top of zone-10,804'.) K~ll well by pumping down casing tubing annulus and circulating through Camco 1.1M mandrel at 10,674' and out tubing. Install Cosasco plug and remove x-mas tree*. Install and test to 3000 psig a Class III BOPE consisting of 10" shaffer LWS Series 1500 Gate and 10" Hvdrill GK Series 1500 preventer. *Note: Send adapter-flange out to be machined for a double bolted Grayloc clamp. 3. Remove Cosasco plug. Pull up and rotate on tubing to release Brown HS-16-1 packer at 10,7.57'. Measure tubing on the-hook while pulling out. Note: Have a Brown "CC" retrieving tool on hand in case the "CC" joint at 10,748' releases. Pull tub- ing slowly. 4. Make up clean out string as follows: 2 3/8" saw tooth collar, 185' of 2 3/8" EUE tubing, balance of string to be 2-7/8" EUE tubing. Run in hole to 10,840' and circulate hole clean. Go through 7" Baker "D" packer at 10,844' and circ~.late at 10,950'±. 5. Run 2 7/8" and 3 1/2" tubing with ABC modifie~ couplings, a Baker model FH packer at ±10,730', and flow control equipment as per the "Proposed Tubing Detail" (to be furnished). Hydro- test all tubing to 6500 psig. 6. Stab tubing through Baker Model "D" packer. When the locator stop contacts the packer, pickup 1 foot and land tubing. 7. Install Cosasco plug. Remove BOPE and install new 10,000 psi z-mas tree. Test tree to 6500 psig with clean water. 8. Remove Cosasco plug and displace clay base drilling fluid with crude oil as directed by Production Foreman. 9. Set CEV valve in the Camco .~.!M mandrel at 10,824'4_.. Set a Brown plug in the 'D" nipple at 10,.843'. Pressure tubing to +_4500 psig to set the P, aker FH packer at 10,755'±. 10. Remove Brown plug. Release rig. 11. As directed by Production Foreman, back flow well from lower zone only, until the zone cleans up. 12. Back flow both zones to clean ~D well. Inject into all zones as soon as surface hook up is complet'ed. JdN30 !97! /S C. W. W. 11. J. W. DIVI~ION OF Oil AND GAS AN'CHORAG~ TP,.ANS.'<ITTAL ,~uND AC ;%EDG>UCqT OF kECE!P7 OF N~-~TERI (AL~S THE FOLLOWING IS A LIST OF ~g~,TERIAL ENCLOSED HEPdZ[.IITH. CHECK AND ADVISE I~V~DIATELY. PLEASE (2) kecuix, ed and checked by: D,2 [_ £~. ** : ~ COMPLETION REPORT - PACKER AND GAS LIFT INSTALLATION STANDARD OIL COMPANY OF CALIFORNIA - WESTERN OPERA2~ONS, INC. - Operator AREA: Keni Peninsula, Cook Inlet Area, Alaska LAND OFFICE: Anchorage Lease No.: A-028406 PROPERTY: Swanson River Unit I~LL NO.: SRU 31-27 Section 27 T. 8 N., R. 9 Wo, Seward B & M LOCATION: Surface: 1730' West and 40' South from Northeast Corner of Section 27. ELEVA?ION: 272' K.B. K.B. is 15' above ground. DATE: August 5, 1963 , / ,~ . /~ o ~ C'~CHATTERTON, District SuPerintendent CONTRACTOR: Santa Fe Drilling Company, Rig #35 DATE CO~*~NCED REMEDIAL ~ORK: MAY 5, 1963 DATE COMPLETED RE~DIAL ~RK: ' MAY 13, 1963 TOTAL DEPTH: 12,O46' PLUGS; 10975' (ti Bridge Plug) 11000' (ti Bridge Plug) 11123' - 11167' 11450' - 11720' CASING: 20" cemented at 22 ' 13 3/8" cemented at 1490' 7" cemented at 11,620' Perforating Record: 2 - -lIt ~' holeS/foot 10,804' - 10,836' Reperforated 2 - holes/foot 10,849' - 10,878' Reperforated UNITED STATES DEPARTMENT OF THE INTER]OR GEOLOGICAL SURVEY LE$SEE'S MONTHLY REPORT OF O?ERAS' L ,VED''''''''''''' JUN 13 196~ ,s'~,~t, Alaska ._ Co~,n~U K_en~__~e_~_a~la ~Y,~d _$~aa~ _8%y~r ................. Petroleum Branch ' Szc. A~, D~r* J J GAL~C~o~ BA~LSO~ REMA!~K~ ~ (~ ~ '!'WP. I~.tXc;g ~ ~ .LJ Paoo{;cm,, ~ BXRRZI.S OW O~.O~XXqrY (In t~ou%nds) OA~OLINE ~'ATEg (If (I~ dri!Un~, depth; ~f sba; down. ~ ' ]{EL'OVE;;FI)llO!le, SO 8[gtC~) dale and result of t~t for ......................... u zr ............................ (2) 27 ; ; work Con~aencea remedial ~y 5, 1702 tre~, and pulled 2 7/8" gating out Set Bakei' Model "NMt . Kille d well, Budget Burm~i No. 4.: Approval expires 12-31~0. ,,:: ~cho~age .. $~s9_~ River :emoved X-mas thei intervals 10, 8C hol~s/fo~t. Condit lanCed ia Baker pac. X-mbs tr~;e. Displ. Rig! rele~Lsed May 1] cc:~ U.S'G.S. - M. Sta'be- T. R. ,h ioned hole and ~et Baker ~" tubing equipped with kef a~ 10,845 '. i Removed ,ced r*d with oi~. Set , 1963 i IH. Scysber l lqarsh all of hole. Ran Ceaaent Bond log. cast iron brid~e plug 10,975.. Reperforated .'-10,836' and 10, 849 '-~O, 878 ' with two 1/2" Hakal~ Model "D" packer at !ac~er an~ m~ndrels and BOPE anal installed acker at 10,757'. NoT~..--There were ....................................... runs or sales of oil; ................................................ M cu. ft. of gas sold; ................................................. runs or sales of gasoline during the month. (Write "no" where applicable.) Nor~.--Report on this for,n is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the supervisor by tho 6th of the succeeding month, unless otherwise directed by the supervisor. Form (Jalttlary 1950) COMPLETION REPORT - P~Km AND GAS LIFT INSTALLATION t' SWANSON RIVER UNIT 31% . t '~ Section 27 T. 8 N., R. 9 W., Seward. B & M STANDARD OIL CO~ART OF CALIFORNIA, %~STERN O?EP~TIONS, INC. - Operator 5, 1,963 Commenced rigging up at 4:00 PM. Oonditoned Black Ma~ic Mud. ,M.a.y.. 6., 1963 Pumped hot oil down tubing to de-wax tubing. Set a straddle packer inside tubing at 2500'. Killed well and removed x-mas tree. ,May 7 ~ 1963 Installed BOPE, pulled tubing loose an8 pulled out of hole. May ,8~ . !963 Ran milling tool and milled on Baker Model "D" packer at 10~ 846'. Pulled and recovered body of packer. Ran bit and casing scraper. Ran bit and casing scraper and cleane8 out to 11~000'. Circulated and conditoned mud. May 9, 1963 Pulled scraper. Ran Cement Bond log 800-10,982' Attempted to run a cast iron bridge plug. Pulled and reran bit.. Cleane~ out to top of plug at 11,000'. May lO, 1963 PUlled out. Ran junk basket. Stopped at 10,975' Pulled tight to 10,930' and pulled out. Ran and set Baker Model N cast i~on bridge plug at 10,975'. Ran Schulmberger Carrier gun and re-perforated the intervals 10,804'_10 ', 836' and 10849-10878'w/~-~ ~'' holes/foot using Crack Jets. ~ay ,!l~ ,1,~63 Ran bit and casing scraper and circulated 6 hours., Reran junk basket. May 12, 1963 Ran Baker ~6del "D" packer on wire line and set 10,846'. Ran a total of 348 joints 2 7/8", 6.5#, N-80 EUE 8R Rg 2 tubing equipped with packer and mandrels. K. B. to Donut Donut Two 2 7/8" pup joints 47 joints 2 7/8" tubing Camco MM Mandrel w/RD '(#1) 33 joints 2 7/8" tubing Camco MM Mandrel w/RD (#2) 30 joints 2 7/8" tubing Camco ~,4 Mandrel w/RD (#3) 22 joints..2 7/8" tubing Camco ~ Mandrel w/R.D. (#4) 17 joints 2 7/8" tubing Camco ~ Mandrel w/R.D. (#5) 14 joints 2 7/8" tubing Camco ~ Mandrel w/RD (#6) 28 joints 2 7/8" tubing Camco MM Mandrel w/RD (#7) 22 joints 2 7/8" tubing Camco MM Mandrel w/RD (#8) 33joints 2 7/8" tubing Camco MM Mandrel w/RD (#9) TUBING DETAIL K.B. Depth 15.00' .85, 15.85' 10.20' 26..05' 1465.85' 1491.90' 13.78' 1505..68' 1036.47' 2542.15' 12.73' 2554.88' 943.60' 3498.48' 12.77' 3511.25' 692.29' 4203.54' 12.71' 4216.25' 523.71' 4739.96' 12.70' 4752.66' 425.27' 5177.93' 12.76' 5190.67' 846.59' 6037.28' 13.63' 6050.91' 659.78' 6710.69' 13.04' 6723.73' 992.00' 7715.73' 12.70' 7728.43' SWANSON R~YER UNIT 31~ Section 27 T. 8 N.~ R. 9 W.~ Seward B & M ,, ,,, STANDARD OIL COMPANY OF CALIFORNIA, WESTERN OPERATIONS, INC. ~erat~r 32 joints 2 7/8" tubing Camco MM Mandrel w/RD (#10) 33 joints 2 7/8" tubing Camco MM Mandrel w/RD (#11) 33 joints 2 7/8" tubing Camco MM Mandrel w/CEV (#12) 2 joints 2 7/8" tubing Brown CC Safety joint One 2 7/8"_pup joint · BroWn 2 7/8" X 7" HS-16-1 packer 2 joints 2 7/8" tubing Camco MM Mandrel w/CEV (#13) One 2 7/8" pup joint Camco "D" Nipple Baker Model "D''~ Seating assembly 953.71' 8682.14' 12.70' 8694.84 ' 985.03' 9679.89' 12.76' 9692.63' 981.57' 10,674.20' 12.6 8 ' 10, 6 86.88 ' 60.70' 10,747.58' 1.O6' 10,748.64' 8.10' 10,756.74' 6.00' 10,762,74' 61.05' 10,823.79, 12.83' 10,836~62' 6.09 ' 10,842 ~ 71 ' · 92' 10,843.63' '63' 10,844~26~ 10,846.OO' 10,850~17' 10,879,73' Top of Midel "D" Packer (wireline measurement) Seal Assembly 5,91'"' Tail pipe 29 ~ 56 ' Tubing landed in "D" packer ~t 10,846' ~ith tail at 10,879.73' Removed BOPE, installed x-mas tree and tested with 4000 psi. O.K.. Displaced mud with oil. sM~Yet 13~. 1963 ~ Brow~ HS-16-1 packer at 10,757' and returned well to production. Rig released at 7:00 AM. S. R. HANSEN SRH/sat Standard O&! ~ of C:ml~Mm~.m · .0. Box 7-839 Upon cmeplet~ of ~he uork; please fLle vL~ ehfJ l~visLon a complete h~ of the eo~ perfomed. APPLICATION FOR PERMIT TO DRILL, DEEPEN OR PLUG BACK APPLICATION TO DRILL El DEEPEN' [] PLUG BACK I-] ~' ~J~ X Address City P. O. Ikat ?-~ . ~ Anehoraro, State DESCRIPTION OF WELL AND LEASE Name of lease ] %Vell number I Elevation (ground) Well location (give footage from section lines) Section~township~range or block & ~urvey Field & reservoir (If wildcat, so state) Distance, in miles, and direction from nearest town or post office Nearest distance from propo.~ed location to property or lease line: feet Proposed depth: I l~(~t-aryi~g~ Number of acres in l~ase; If lease, purchased with one or more wells drilled, from whom purchased: Name County Distance from proposed location to nearest drilling, completed or applied--for well on the same lease: ;rox, date work will start Number of wells on lease, including this well, completed in or drilling to this reservoir: Address feet Status of bond Remarks: (If this is an application to deepen or plug back, briefly describe work to be done, giving present producing zone and expected new producing zone) 'RECEIVED MAY 6 Petroleum Branch of Mines ch:' .4;~erO~ CERTIFICATE: I, the undersigned, state that I am the~.~ke%,, :'~ ~.~-of the. ~~' (company), and that I am authorized by said company to make this report; and that this report was pre- pared under my supervision and direction and that the facts stated therein $~{tr~e,~, ~orr~t ~,~4~ complete to the best of my knowledge. ~C~ Permit Number: , ,,~/~/~t d' Approval Date: /~, ? '/~ '~ Notice: Before sending in this form be sure that you have given all information requested. Much unnecessary correspond- ence will thus be avoided. See Instruction on Reverse Side of Form Signature Alaska Oil and Gas Conservation Commission Application to Drill, Deepen or Plug Back Form No. P-1 Authorized by Order No. 1 Effective October 1, 1958 APPLICATION FOR PERMIT TO ~ DEE."."N OR PLUG BACK ~~r?.~~ APPLICATION TO DRILL [] NAME OF COMPANY OR oPERATOR DEEPEN [] PLUG BACK I][ DATE Address City State DESCRIPTION OF %VELL AND LEASE Name of lease %Vell number Elevation (ground) S~anson River ~nit 31-27 (2) 2~7 XVe]I location (give footage from section lines) Section--~township--range or block & survey App~ax. 17~O' W*l_v. alo~ ~. line & 40t S*A~..~A fr~m NE Cot. Sec. 27: T~: RgW Field & reservoir (If wildcat, so state) I County $~anson ~fiver }iel~, f~aX~k ~servoirI Xemai Distance, in miles, and direction from nearest town or post office 16 mil~ ~. of Sterling: Alaska Nearest distance from proposed location to property or lease line: 1730 feet Rot~ary ~ Distance from proposed location to nearest drilling, completed or applied--for well on the same lease: NOt Applicable feet I~ ~ ~'~ate ~or~ star~ gu~ 22:1960 __~ot,~ Depth 12:046' Number of acres in lease: Number of wells on lease, including this well, completed in or drilling to this reservoir: If lease, purchased with one or more wells drilled, from whom purchased: Name Address Status of bond ~ene Remarks: (If this is an application to deepen or plug back, briefly describe work to be done, giving present producing zone and expected new producing zone) It is p~po~ ~ot 1. ~ter well a~ a%temp~ to locate ~a%er entry by selec%ively t~stir~ each pre~ue%ive ~ ~iv~l~. 2. At,pt to el~~te ~a~r ent~ with .~ent pl~, ~c~rs, ~ o~ 3. ~c~ well. Stan~ 0il Co. of Ca~~. CERTIFICATE: I, the undersigned, state that I am theD,~.~Ap_ t. of the '~*]~-~g~ ~1'~;: i~. Approved. (company), and that I am authorized by said company to make this report; and that this report was pre- , pared under my supervision and direction and that the facts stated ther~a .ar9 tr]~e, .correct and complete to D. D. Bruce, Petrole~ ~ol~i~ knowledge. ~o T. CaOOKE Division of Mines and Minerals Alaska Dep~ c~ Natural Re~oure~ Signature,,, , Je To Croo~r Permit Number: Approved By: Notice: Before sending in this form be sure that you have given all information requested. Much unnecessary correspond- ence will thus be avoided. See Instruction on Reverse Side of Form Alaska Oil and Gas Conservation Commission Application to Drill, Deepen or Plug Back Form No. P-1 Authorized by Order No. 1 Effective October 1, 1958 SUNDRY NOTICES AND REPORTS ON WELI~ (INI]II~AI~ AIOq~ IIY ~J4lr. K MA~K I~kTUM JOJI' IJJ'OJiq'. ROJ[ ~ DATA) DETAIL~ OF WORK 2. Pull ~btng. 3. Reperfora~e in~erwkl. 10804-10836' & 10849-10878_~'.~. 4. Re-run tubing vi~.h gas lift mandreln and packern. ~. Cessplete well. 'RECEIVED' MAY 6 1963 Petroleum Branch Division of Mines Alaska Dept. of I'-:,'~ ,. COMPT.W~TION REPORT - REMEDIAL STANDARD OIL COMPANY OF CALIFORNIA - WESTERN OPERATIONS INO. - OPERATOR -~1,1 111 __, , ,,,jl , . I ,1, , _ , ,! , il, , i , , , i , iii 11 AREA: Ken~! Peninsula, Cook Inlet Area PROPERTY: Swanson River Unit LAND OFFICE: Anchorage Lease No.: 028406 WELL NO.: SRU 31-27 SEC.: 27 (Proj.) T. 8 N., R. 9 W., Seward B & M LOCATION: Surface: 1730' West and 40' south from NE Corner Section 27 (Projected) T. 8 N., R. 9 W., Seward EIEVATION: 289' K. B. DATE: October 26, 1960 ~ ~.~ B. ~is 15' above ground. J. T~OKER, DiStrict Superintendent DP~T.!.ED BY: Coastal Drilling Company DATE COMMENCED DRILLING: July 22, 1960 DATE COMPLETED DRILLING: August 5, 1960 DATE OF INiTIAL PRODUCTION: Shutin pending installation of production facilities. SUMMARY TOTAL DEPTH: 12,046' PLUGS: 11,720 - 11,450' 11,167 - Ll, 123' 11, 000 ' (C. I · Bridge .. CASING: 20" Conductor cemented at 22' 13 3/8" Casing cemented at 1,490' 7" casing cemented at 11,620' ' RD 1 ~l t PERFOPATION EECO : 5 - ~ holes 10,889 - 10,890 . DRILL STEM TESTS. 1. HOT On perforated interval 11,0~8 - 11,660' 2. HCT on perforated interval 10,849 - 10,878' B- HCT on perforated interval 10,804 - 10,836' 4. HOT on perforated interval 10,889 - 10,890' (NSO) roi1 & Gas Section :Budget Bureau No. 42-R35¢.5. DEPARTMENT OF THE INTERIOR L[~E NUMBER ._,,~_,,._..~_,.:~ GEOLOG I CA L S U RVEY u NIT .....~'.~L~[ 55~L_ LESSEE'S MONTHLY REPORT OF OPERATIONS' State ..... ~_r~. ................... County : '' P" ~" '~ '~ "'~ TI~e £ollowin~ is a correct report of operations a~,d prod~ct~o~ (l~cl~d~n~ drglH~ a~d prod~c~n~ wells) for the mo~th of .................. ~)!%~ .................. Lg.~., &:,:~.n~-~on --~ - ................................. ~-~ .... 7 ..... ;?"-'~ ........... J~e~t' s address __2,.~) ~}~t__;:-~'.~ .................................. Company ___~:_~<~c~.~__~~c~.:~2~ ....... P ~o n e ..................)Z)A~_~_~_Ct:~: ............................................... CU. FT. O¥ GAS { GALLONS OF t BAaRE~S o~ REMARKS BABREL8 Or OIL GRAVITY (In the~ds) [ GASO~NE ~ WXTrR (If (If ~1i~, d~pth; ii ~hu~ down, i f.ro:,~ i], ...,:':~,. t~ 1].,C:',..~, f"l..~e<~ oil :::~t O0 t-c i~0 B~ rate, , ~ '-:~ . ~ L:. S, Ohio S'nicn ., NoTE.~There were ....................................... runs or sales of oil; ............................................. M cu. ft. of gas sold; .............................................. runs or sales of gasoline during the month. (Write "no" where applicable.) NoTre--Report on this form is required for each calendar month, regardless of the sta[us of operations, and must be filed in duplicate with the supervi~r by the 6th of the succeeding month, unless otherwise directed by the supervisor. (January 19~0) Au~dst 8, 1960 ~ ~'. Crooker: Please be ~lv~od that you~ appl~ca.tLon co plug ~ re-work ~elX ~, ,, h~coU of t~ ~rk ~rfoM, S~te ~etFolemu G~olo~tst UNITED STATES DEPARTMENT OF THE INTERIOR GEOLOGICAL SURVEY LESSEE'S MONTHLY REPORT OF OPERATIONS State .._.&~...g.¢.ga ................. County ..K_~ pe!.'~.nsu~... Pield ...... ~%.~._r._so.l~. !~ver ............................... 5I%c follou~in~ is a correct report of o,,)cr,~ions a~,d proJuction. (i~clu. din~ drillin~ and prod~cin~ wells) for thc m. on. tl~ o/_ ..... A~&~sg ..... 19_~_, ._ . ~~ ~v~r ............................ , , ...., · 0~, ', OF A~F. "" 302 - 27 gN 9W Set~ at ll,t~~ i P.e~'d. 5 - -~ hoZes 10, ~, '- -,, , ~ted for~O on pe~s 10,859 - IC:,:5~, ~st ~. Set p~d~.ctlon pacier at 10,8~'. ~n R 7/5" tubi~. !~stal!e~ ~is~l~c~ ~'il!1~ ffluid ~ ~::~de oil. Flo~d clean 'O- Flowed e~ti~mted. 350 B/D ~ti~ ~/~. ~teas~d cc: UoSJG,8~ ~.-M, N. ~yster (3) ~fiel 01i Co~. - C. W. PoF~ bL L. ~I1~ W~ C. Bis , , R.J. i~sbeek Ohid Oil ~o. - ~or~e So~rds UniQn oil, Co~ - C. E~ ~th ~ P~duci~ NoTE.---There were .......................................... runs or sales of o5!; ..... ............................................... M cu. ft, of =,~:~s~ sold', ' ~ (Write ' "w~::rc ai~plicai)lr;.~ No-no ....... i{ep(')rt on tllis form is req,i]r,~d fc,r oa.,:'~ ('.,a.iu~dr~r nlon~h -' ,' ,, (,hmuary 1950) F~ODUC~rlON DATA 1,8' _ ue~r ~i}s _ RECORD _ _ lOOO psi for 30 mlA~ ok _ DAT~ OF ~TL~L ~om~om J _anu~..~ 6~ ~9~ ./ OCT Divlsio2il & Oas Section of i~dis~es a~d Minerals Alaska DeFt. of ~'~(~amra/ }~esource~ ... Picked tip ~,11 ~ aad stared coadlttoai~ mud tn sta~s. - ' ' '/'::'- .... ,.,,~ Form 9-881a (Feb. (SUBMIT IN TRIPLICATE) UNITED STATES DEPARTMENT OF THE INTERIOR GEOLOGlCAL SURVEY Bud~Z Bur~u No. 42-R3156.~. Approval expires 12-31-~). SUNDRY NOTICES AND REPORTS ON WELLS INTENTION I*~1 II I NOTICE OF TO CHANGE I II ! .o.r,= o~ ,.~,.,o..,-o.,oo~- 0" '~"~'= .................. l ...... II su,,.~oo,..,',*,~.'r o~,,~.~.,,,~.',* ....................... *°-I ..... ,,o~*,= o,~ ,.~..,o.','o,*u,, o,,.,.'~ ~,~,.~ .............. I ...... II ~o,*~,,,,..*,,,.. w~.,~o,.. ................................... I ..... (INDICATE ABOVE BY CHECK MARK NATURE OF REPORT, NOTICE, OR OTHER DATA) Well No ....... a ......... is located I__ ft. from__ t~'[ line and ft. fro sec. __~ ........ ~~__~__~: ............. ~_~ ............. ~_:~: .......... ~~ ............. (~ See. nn~t See. No.) (Twp.) (Range) (]Kefldlsn) .......... ~_~~_~_ ........... ~_~ ........................... ~._ .................. (Field) (County or Subdivision) (State or Territory) The elevation of the sea level is ~ ...... ft. DETAILS OF ~VORK (State names of and expected depths to objective sands; show sizes, weights~and lengths of proposed casingsI indicf~te mudding jobs, cement- ing points, and all other important proposed work) I understand that this plan of work must receive approval in writing by tho Geological Eurvey before operations may be commenood. Company _~_~,_~__~-~_:~_~_, .:~. ............................ Origlnal slgned Ad&~ __~t__~__~__~~ ......................... J.T. CROO~C~ By .... -~i;-~-~ .......................... Title ~~__ GPO 9. 18 ~07
