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167-068
MEMORANDUM TO: Jim ReggG� P.I. Supervisor FROM: Guy Cook Petroleum Inspector Well Name MGS A33-14 Insp Num: mitGDC211022122312 Rel Insp Num: NON -CONFIDENTIAL State of Alaska Alaska Oil and Gas Conservation Commission DATE: Monday, November 1, 2021 SUBJECT: Mechanical Integrity Tests Hilcorp Alaska, LLC A33-14 MGS A33-14 Src: Inspector Reviewed By: P.I. Supry �7>L-- Comm API Well Number 50-733-20057-00-00 Inspector Name: Guy Cook Permit Number: 167-068-0 Inspection Date: 10/14/2021 L, - Packer Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min �ype Int w - TVD -- --- PTD I 67o6ao -Type Test SPT � est psi 9 � Tubin � 14so laso laso +' t600- 1980 IA 623 2222 2215 --- 2212 - BBL BBL Pumped os 7 - 7 7 -. - Returned: � 0 6 OA s - i— Interval 4vRTST_ P/F -- - Notes: Testing completed with a small triplex pump and calibrated gauges. Monday, November 1, 2021 Page 1 of I • S MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg DATE: Thursday,October 26,2017 P.I.Supervisor hei t wI Z-7(17 SUBJECT: Mechanical Integrity Tests HILCORP ALASKA LLC A33-14 FROM: Jeff Jones MGS A33-14 Petroleum Inspector Src: Inspector Reviewed By: P.I.Suprv6 — NON-CONFIDENTIAL Comm Well Name MGS A33-14 API Well Number 50-733-20057-00-00 Inspector Name: Jeff Jones Permit Number: 167-068-0 Inspection Date: 10/10/2017 Insp Num: mitJJ171024170910 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well J A33-14 Type Inj 7 W "TVD 7922 Tubing 3523 3500 3500 ' 3500 PTD 1670680 Type Test SPT Test psi 1980 " IA 240 2224 - 2212 - 2209 - BBL Pumped: 1 BBL Returned: 1 OA 0 • 16 12 12 Interval 4YRTST P/F P Notes: 1 well inspected,no exceptions noted. ./ Thursday,October 26,2017 Page 1 of 1 • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission Jim Re C I DATE: Monday,October 09,2017 TO: P.I.Supervisor I `� '�`�(I SUBJECT: Mechanical Integrity Tests HILCORP ALASKA LLC A33-14 FROM: Lou Laubenstein MGS A33-14 Petroleum Inspector Src: Inspector Reviewed By: P.I.Supry NON-CONFIDENTIAL Comm Well Name MGS A33-14 API Well Number 50-733-20057-00-00 Inspector Name: Lou Laubenstein Permit Number: 167-068-0 Inspection Date: 9/26/2017 Insp Num: mitLOL170929154904 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well A33-14 . TType Inj w • TVD 7922 Tubing, 3150 3150 " 3150 ' 3150 3150 • PTD 1670680 Type Test SPT Test psi 1980 IA 590 2234 - 2269 - 2305 2337 BBL Pumped: 1 BBL Returned: 1 OA I 10 j 10 • 10 10 - 10 ----------....---- Interval 4YRTST IP/F I ✓ Notes: Inconclusive due to increasing IA pressure during test and gas-cut fluid returned after test. Monday,October 09,2017 Page 1 of 1 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission Monday, September 30, 2013 TO: Jim ReggDATE: 1�p' (� 3 P.I. Supervisor 14 SUBJECT: Mechanical Integrity Tests XTO ENERGY INC A33-14 FROM: Jeff Jones MGS A33-14 Petroleum Inspector Sre: Inspector Reviewed By: P.I.er;Supry 3 2 — NON -CONFIDENTIAL Comm Well Name MGS A33-14 API Well Number 50-733-20057-00-00 Inspector Name: Jeff Jones Permit Number: 167-068-0 Inspection Date: 9/16/2013 Insp Num: mitJJ130924183952 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min ------ -- - ----- Well' A33-14 Type Inj W 'TVD 7922 IA i - 300 2230 = 2220 -1 2220 PTD Type Test Test psl OA 1670680 SPT 1980 0 0 0 0 Interval INITAL P/F P Tubing 3200 , 3200 3200 3200 Notes: Initial MIT. 1 well inspected, no exceptions noted Monday, September 30, 2013 Page I of I Brooks, Phoebe L (DOA) Pt*I 167060 From: Phillips, Barney[Barney_Phillips @xtoenergy.com] Sent: Friday, September 27, 2013 3:01 PM To: Brooks, Phoebe L (DOA) Subject: RE: MGS -XTO Energy- MIT Reports Attachments: A33-14 WIW Current WBD 6-25-13.docx; C24-23 WIW Current WBD 5-20-13.docx Here they are Phoebe. If you need any further information, please let me know. Barney From: Brooks, Phoebe L (DOA) [mailto:phoebe.brooksOalaska.gov] Sent: Friday, September 27, 2013 7:39 AM • To: Phillips, Barney Subject: RE: MGS -XTO Energy - MIT Reports Thank you. Phoebe Brooks Statistical Technician II Alaska Oil and Gas Conservation Commission Phone: 907-793-1242 �� !t 0 9 frli Fax: 907-276-7542 From: Phillips, Barney [mailto:Barney Phillips(axtoenergy.com] Sent: Thursday, September 26, 2013 4:27 PM To: Brooks, Phoebe L(DOA) Subject: RE: MGS -XTO Energy - MIT Reports Hi Phoebe, The schematics I have here on the platform are labeled "Proposed" in the header and I do not have the program to change it. Our engineer is going to send me the updated copies tomorrow and I will get those to you as soon as I get them. Thanks! Barney From: Brooks, Phoebe L (DOA) [mailto:phoebe.brooks@)alaska.gov] Sent: Wednesday, September 25, 2013 1:50 PM To: Phillips, Barney Subject: RE: MGS - XTO Energy - MIT Reports Thank you. Phoebe Brooks Statistical Technician II Alaska Oil and Gas Conservation Commission Phone: 907-793-1242 Fax: 907-276-7542 1 • J1"O AAA 6/25/2013 ENERGY MGS A33-14 WIW Cook Inlet, Alaska CURRENT COMPLETION Leg 4,Conductor 30 ,��� Item Length,ft Top Bottom ire' API No.: 50-733-20057 9 jts 2-718"tbg 276 38 314 Spud: 11/02/1967 L.. / i 10'2-718"Pup Jt 10 314 324 Surf Cs Xnipple(2.313"ID) 1 324 325 S g 10-3/4" 40.5#, J55 1,890'. ♦ 10'2 Pup Jt 10 325 335 @ F 2-7/8"6.5#1%8rd EUE tbg 9,066 335 9,401 Cmt w/1,500 sx cmt.Top out w/475 sx cmt. X0 2-718"X 2-318" 1 9,401 9,402 Original Prod Csg: 3 its 2-318"8rd EUE tbg 96 9,402 9,498 7",23#, N80 BTC: 0-6,435' 10'2-3/8"Pup Joint 10 9,498 9,508 7", 26#, N80 BTC:6,435'-9,831' 2 318"XU Sliding Sleeve w X Profile IwirbAnoo> 4 9,508 9,512 7", 29#, N80 BTC: 9,831'-10,531' 10'2-318"Pup Joint 10 9,512 9,522 Cmt w/1,100 sx cmt. 6'2 318"Pup Joint 6 9,522 9,528 7/14/00: : ., 2.68F Locator wl 10'Seal Assembly 1 9,528 9,529 Cut 7"csg @ 88'. Ran OS&7",46.2#csg 5"Model'D'Perm Packer(Tripoint) 2 9,529 9,531 &install new WH and SS tree. ; Concentric Pkr Bottom Adapter 1 9,531 9,532 ♦.�O%i +� �-+# Seal Bore Extension 9 9,532 9,541 ♦ �, . ��� 05/21/84: ! ���� Y �i�i�i Crossover 2 3/8"x 2 718"8rd EUE 1 9,541 9,542 ` 6 9,542 9,548 cmt Csg leak @ 6,150'. Sqz'd w/200 sx Cl G '��.# � ��*� 2 318"x 6'pup jt `� - 1 jt 2-3/8"4.7#8rd EUE tbg 30 9,548 9,578 i 4 2-3/8"x 4 pup jt 4 9,578 9,582 �_ XN ni le 1.791"ID) 1 9,582 9,583 VA`} 2-3/8"x 8'pup jt 8 9,583 9,591 1 jt 2-3/8"4.5#8rd EUE tbg 30 9,591 9,621 ,,//�� WLREG 1 9,621 9,622 TO) / 9,622 ,, ,i►, Note on perfs: all original perfs sgz'd & covered w/5"liner. Re-perfd all intervals 5/28/84: 1 except G members, HE-HF &HI HK. Ran 5", 18#, N80 SFJP liner fr/8,956'- 10,432'. ,�//%� cmt w/150 sx Cl G cmt. �,/,l ! r GN-GO:9,061'-9,083' (Behind 5"Liner) GR-GS: 9,435' 9,451'(Behind 5" Liner) 7/16/00: GR-GS:9,456'-9,472' (Behind 5"Liner) Ran 5", 18#, N80, Hydril 513 tie-back liner fr/ 0100 . 8,956'-surf. ; HC-HD: 9,715'-9,804' (Behind 5"Liner) Cmt w/132 bbl Cl G cmt. Circ cmt to surf. +�� HC HD: 9,715' 9,804' ,,,,� + HE-HF: 9,860'-9,888' (Behind 5" Liner) �/ �� HI-HK: 9,954' 9,995' (Behind 5" Liner) ,,I/,� . HK-HN: 10,008'- 10,162' (Behind 5" Liner) 4 " / HK-HN: 10,060'- 10,162' rifril 110 ' HN-HR: 10,173' 10,239' (Behind 5"Liner) HN-HR: 10,162'- 10,239' / t �� HN-HR: 10,261'-10,302'(Behind 5" Liner) +t/ + / HN-HR: 10,260'- 10,302' flw", HR-HZ: 10,328'- 10,460'(Behind 5" Liner) OIL. �� HR-HZ: 10,328'-10,419' PBTD: 10,432' .,, 05/21/84: TD: 10,555' e: All perfs sgz'd w/250 sx cmt below CICR @ 9,593'. STATE OF AKA ALA.OIL AND GAS CONSERVATION COMMON EC E'V E® t REPORT OF SUNDRY WELL OPERATIONS SEP 12 2013 1.Operations Abandon U Repair Well a Plug Perforations Li Perforate U Other LAOGCC Performed: Alter Casing ❑ Pull Tubing El Stimulate-Frac ❑ Waiver❑ Time Extension❑ Change Approved Program ❑ Operat.Shutdown❑ Stimulate-Other ❑ Re-enter Suspended Well❑ 2.Operator XTO Energy 4.Well Class Before Work: 5.Permit to Drill Number: Name: Development ❑ Exploratory ❑ 167-068 • 3.Address: 9127 S Jamaica St,Englewood,CO 80112 Stratigraphic❑ Service 0 6.API Number: 50-733-20057-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL 0018756 ' Middle Ground Shoal A33-14 . • 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): MGS E, F, G Pools • 11.Present Well Condition Summary: Total Depth measured 10,555 feet Plugs measured NA feet true vertical 8,816 feet Junk measured N/A feet Effective Depth measured 10,432 feet Packer measured 9,529 feet true vertical 8,704 feet true vertical 7,909 feet Casing Length Size MD TVD Burst Collapse Structural Conductor Surface 1890' 10-3/4" 1890' 1763' 3130 psi 1580 psi Intermediate 10531' 7" 10531' 8794' 6340 psi 3830 psi Production 10432' 5" 10432' 8705' 10140 psi 10490 psi Liner Perforation depth Measured depth 9715-10419 feet SCANNED j r ',r ,¢. 3 f O'� True Vertical depth 8073-8693 feet ��da Tubing(size,grade,measured and true vertical depth) 2-7/8",6.5#,L-80,EUE,8rd;EOT @ 9,621'MD 7,985'TVD Packers and SSSV(type,measured and true vertical depth) 5"Model D Perm Pkr @ 9,529' MD 7,909'TVD; 'X' Nipple @ 324'MD, 324'TVD 12.Stimulation or cement squeeze summary: Intervals treated(measured): 13. Representative Daily Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: NA NA 500 0 3500 psi Subsequent to operation: NA NA 1200 0 3500 psi 14.Attachments: 15.Well Class after work: Copies of Logs and Surveys Run Exploratory❑ Development Service El Stratigraphic ❑ Daily Report of Well Operations Yes 16.Well Status after work: Oil ❑ Gas ❑ WDSPL❑ GSTOR ❑ WINJ 0 • WAG ❑ GINJ ❑ SUSP p 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: 313-013 Contact Sandra Haggard Email Sandra Haggard@xtoenerQV.com Printed Name Title Regulatory Analyst /� Signat,44012. :,..— ;, Phone ,3d - 97- �G7.L. Date Tj Q'A.3 t Form 10-404 Revised 10/2012 /0 ///J RBDAA§mit Q i 1al,�ni t 1 fs I e f--/0 [7 JJ tt Y/ (1J /TO ERGY August 28, 2013 Alaska Oil and Gas Conservation Commission Attn:John Norman,Commissioner 333 W.7th Ave.,Suite 100 Anchorage,Alaska 99501-3539 Re: Form 10-404, report of sundry well operations Objective: Pull tubing and repair well Middle Ground Shoal#A33-14 Water Injection Well Middle Ground Shoal Field E, F&G Pool Cook Inlet,Alaska API 50-733-20057-00 XTO Energy hereby submits the report of sundry well operations to pull the tubing, packer and replace will new completion string. Enclosed are the following attachments: 1. Form 10-404 Report of Sundry Well Operations 2. Workover Daily Activity Report 3. Current Wellbore Diagram If additional information is required, please contact me at 303-397-3672 Sincerely, 4rC.Z.Pc214. .---X/*ert41/ Sandra Haggard, Regulatory Analyst Copy to: Bola Adeyeye,Operations Engineer,Office: 303-397-3606 J • s AAA 6/25/2013 ;fro ENERGY MGS A33-14 WIW Cook Inlet, Alaska PROPOSED COMPLETION Leg 4,Conductor 30 Item Length,ft Top Bottom API No.: 50-733-20057 9jts 2-718"tbg 276 38 314 Spud: 11/02/1967 ...• �// 10'2-7/8"Pup Jt 10 314 324 : X-nipple(2.313"ID) 1 324 325 Surf Csg: :' -• 10-3/4", 40.5#, J55 @ 1,890'. 10'2-7/8"Pup Jt 10 325 335 Cmt w/1,500 sx cmt.Top out w/475 sx cmt. 2-7/8"6.5#1%8rd EUE tbg 9,066 335 9,401 X0 2-7/8"X2-3/8" 1 9,401 9,402 Original Prod Csg: 3 jts 2-3/8"8rd EUE tbg 96 9,402 9,498 7",23#, N80 BTC: 0-6,435' 10'2-3/8"Pup Joint 10 9,498 9,508• 7", 26#, N80 BTC:6,435'-9,831' 2 3/8"XU Sliding Sleeve w X Profile(remb"rton) 4 9,508 9,512 7",29#, N80 BTC: 9,831'-10,531' 10'2-3/8"Pup Joint 10 9,512 9,522 Cmt w/1,100 sx cmt. 6'2-3/8"Pup Joint 6 9,522 9,528 7/14/00: :::: .::: 2.688" /14/00: 2.688"Locator w/10'Seal Assembly 1 9,528 9,529 Cut 7"csg @ 88'. Ran OS&7",46.2#csg 5"Model'D'Perm Packer(Tripoint) 2 9,529 9,531 &install new WH and SS tree. Concentric Pkr Bottom Adapter 1 9,531 9,532 '.i :: Seal Bore Extension 9 9,532 9,541 �+++ :: 05/21/84: ..• ++*+.: Crossover 2 3/8"x 2 7/8"8rd EUE 1 9,541 9,542 +++ ►+++� 7"Csg leak @ 6,150'. Sqz'd w/200 sx Cl G +�+ ::: +++++++i 2-3/8"x 6' u t 6 9,542 9,548 .1+++ ,:::. ::'+A 1. pup j cmt. `+.!: 1 jt 2-3/8"4.7#8rd EUE tbg 30 9,548 9,578 iiii 2-3/8"x 4'pup jt 4 9,578 9,582 :.: (1.791"ID) 1 9,582 9,583 .� :::: XN nipple( ) �.. 2-3/8"x 8'pup jt 8 9,583 9,591 1 jt 2-3/8"4.5#8rd EUE tbg 30 9,591 9,621 : WL REG 1 9,621 9,622 :. 9,622 • Note on perfs: all original perfs sqz'd& `: covered w/5"liner. Re perfd all intervals 5/28/84: � ,: ::� except G members, HE-HF& HI-HK. Ran 5", 18#, N80 SFJP liner fr/8,956' 10,432'. :.• Cmt w/150 sx Cl G cmt. GN-GO:9,061'-9,083'(Behind 5" Liner) i, .. + � GR-GS: 9,435'-9,451' (Behind 5"Liner) 7/16/00: +� 1r GR-GS:9,456'-9,472'(Behind 5" Liner) Ran 5", 18#, N80, Hydril 513 tie-back liner fr/ ►�. ��� ■ 8,956'-surf. ►+� �+ (+� HC-HD: 9,715'-9,804' (Behind 5" Liner) Cmt w/132 bbl CI G cmt. Circ cmt to surf. w . HC-HD: 9,715'-9,804' . HE-HF: 9,860'-9,888' (Behind 5" Liner) . : �-' HI HK: 9,954' 9,995' (Behind 5" Liner) �(►+* _ + !+__ HK-HN: 10,008'- 10,162' (Behind 5" Liner) * HK-HN: 10,060'- 10,162' • HN-HR: 10,173'- 10,239'(Behind 5" Liner) �►i :;, HN-HR: 10,162'- 10,239' ►*� HN-HR: 10,261'-10,302'(Behind 5" Liner) I// HN-HR: 10,260' 10,302' 4402 HR-HZ: 10,328'-10,460'(Behind 5" Liner) ■ ' HR-HZ: 10,328'- 10,419' PBTD: 10,432' � 40 05/21/84: TD: 10,555' / All perfs sqz'd w/250 sx cmt below CICR @ 9,593'. 4 tally Activity and Cost Summary_sls ENERGY Well Name: Middle Ground Shoal A33-14 INJ APINWI Location Field Name Permit Number State/Province Well Configuration Type 50733200570000 TO8N-R13W-S11 Middle Ground Shoal 167-068 Alaska Directional Original KB Elevation(ft) Gr Elev(ft) KB-Ground Distance(ft) Spud Date .Rig Release Date Total Depth(ftKB) 116.00 0.00 ; 116.00 1/1/1969 Jobs Job Category Primary Job Type/Initial Job Type Secondary Job Type/Final Job Type Start Date End Date Well Maintenance Repair Hole in Tubing 6/19/2013 00:00 8/1/2013 00:00 Objective Summary Daily Operations Rpt No. Report Start Date Report End Date Operation Summary#1 1.0 6/18/2013 6/19/2013 Continue to get drilling equipment ready to move to Platform A.Rig up slick line and complete slick line work on well.Pull GLM#9 and displace well bore at 3.5 bpm.Pull out bar and prong under 7"packer. While sliock line work is being performed,continue rigging down equipment that will be sent to platform A. Plan ahead:Send small crew over to Platform A to make deck ready for the equipment to be transfered fron platform C.Get ready to move derrick over to A33-14 before we start moving equipment. Remarks#2 Construction Summary#3 Rpt No. Report Start Date Report End Date Operation Summary#1 2.0 6/19/2013 6/20/2013 Continue rigging down drilling equipment to move to platform A.Cut and slip drilling line.Continue work on removing tools from floor,to include gas buster,choke lines,circulating hoses,iron roughneck and HPU from the cellar.Make 2 boat loads to go to Platform A and to shore.Send crew to platform A and keep one crew here on Platform C. Plan forward:Continue rigging down on Platform C and get ready for boat to haul equipment to Platform A.Move derrick over to well A33-14.Start washing rig on Platform C. Remarks#2 Construction Summary#3 Rpt No. Report Start Date Report End Date Operation Summary#1 3.0 6/20/2013 6/21/2013 Continue to rig down equipment on Platform C and start moving derrick on Platform A over well A33-14. On platform A:Cleared deck on leg#4,welder cut south crane boom rest and relocated on leg 3. Inspected jacking system,installed jacking cylinders,troubleshoot HPU and found system needs servicing.Cleaned and lubricated skid rails on sub base.Need to bring over skid system from Platform C to use on A.Plumed in air to rig and inspected and function tested tuggers and spotted choke manifold on rig floor.Set hook in V-door.Set iron roughneck on catwalk.Stage BOPE on leg 4 to access cellar.On Platform C:clean pits,chain down blocks,Pull BOP trolleys,and extension rails. Prepare loads for boat,rig down man rider.Fill pit#3 with FIW and prepare for injecting.Rig down 4" and 6"choke lines.Organize hard lines that stay on rig.Prepare for boat. Plan ahead:Boat was postponed until 10:00 today,we will use it for 24 hours to load everything off of Platform C and send to platform A.WE will send the jacking system from C to A to move derrick.We will start to clean the derrick and decks of Platform C.Platform Awe will start to install drilling equipment,and organize deck. Remarks#2 Construction Summary#3 • Rpt No. Report Start Date Report End Date Operation Summary#1 4.0 6/21/2013 6/22/2013 Started loading boat from Platform C to go to Platform A.Loaded beaver slide,#7 HPU,portable HPU, antifreeze barrels,kelly skid,slop tank,corrosion inhibitor,lay down slide,kelly,portable choke,super choke control,spreader bar,man rider,Nitrogen bottles,metal basket,parts and tools to connex.Inject storage tanks with 225 bbls and chase with 225 bbls FIW.Flush and blow down pumps,inspect pumps, clean pump room,clean rig floor,work on racking board drains.Palatize and prepare for boat.Off loaded boat on Platform A and organized for rig move. Plan Forward:Continue cleaning rig and deck on Platform B.On Platform A,move derrick and start rigging up over A33-14 well.Last boat to be loaded on Sunday. Remarks#2 Construction Summary#3 www.xtoenergy.com Page 1/9 Report Printed: 9/10/2013 .4 gaily Activity and Cost Summary_st i:1 k:II ti]' Well Name: Middle Ground Shoal A33-14 INJ API/UWI Location Field Name -Permit Number State/Province Well Configuration Type 50733200570000 TO8N-R13W-S11 Middle Ground Shoal 167-068 Alaska Directional Original KB Elevation(ft) Gr Elev(ft) KB-Ground Distance(ft) Spud Date Rig Release Date Total Depth(5KB) 116.00 0.00 116.00 1/1/1969 Daily Operations Rpt No. Report Start Date Report End Date Operation Summary#1 5.0 6/22/2013 6/23/2013 Continue to clean rig at Platform C.Organize top deck,pull blower motors off of DW-B;MP-1B;MP-2B and get ready for boat.Clean drains on rig floor,remove hoses from rig floor drains.Repair pressure washer,disconnect Power T.Clean back deck,move loading dock,disconnect electrical cords.Finish getting storage ready for boat to take to A.Continue rigging up Platform A.Moved rig to within 10'of A33-14 spot on platform. Plan ahead:Load boat fron Platform C to go to Platform A.Off load boat on A and organize equipment for rig when rig is in place.Continue cleaning All decks and rig on Platfom C. Remarks#2 Construction Summary#3 Rpt No. Report Start Date Report End Date Operation Summary#1 6.0 6/23/2013 6/24/2013 Continue cleaning Platform C.Roll up all electrical lines and tie up on a pallet.Cut out auger from pits, wrap DW and drillers consol,remove chains and bindings F/parts house and change house and prepare for boat.load out boat for Platform A and then send load to shore.Start deep cleaning rig before leaving.On Platform A welder put in pad eyes on I-beams in sub base.Install BOPE stack and trolleys in cellar on derrick and start installing drilling tools to get ready for operation on A33-14.Off loaded Boat from C.Spotted HPU,test pump skids in sub.Place double gate and annular Preventer in sub,swapping jacking cylinders for other side of rig. Plan forward:Continue deep cleaning on Platform C and rigging up drilling tools on Platform A.Send Day tool pusher,derrick hand and pit watcher to Platform A.Keep 4 hands here to do deep cleaning until wednesday when a new crew will come out and we will split tours to finish installing tools on A. Remarks#2 Construction Summary#3 Rpt No. Report Start Date Report End Date Operation Summary#1 7.0 6/24/2013 6/25/2013 Continue to do deep cleaning on rig at Platform C to get ready to release the rig.Cleaned cellar and organized everything on ntop deck.Continue rigging up drilling tools on Platform A,remove hatch covers,main air lines,Cut out rusted hand rails,set up change shack and parts connex.Organize tools and parts in pump room.Install blower motor on generator#2.Fill HPU with hydraulic oil.Place kelly sock in welding shop to repair.Quadco to prepare to install rig watch. Plan ahead:Finish cleaning rig on Platform C.Continue rigging up tools on Platform A.. Remarks#2 Construction Summary#3 Rpt No. Report Start Date Report End Date Operation Summary#1 8.0 6/25/2013 6/26/2013 Continue cleaning rig on Platform C,finished deep cleaning of top and lower deck,moved three hands over to A and finished up cleaning on C.Continue setting tools on rig on platform A.Centered rig over well A33-14.RD skidding unit,moved drilling line spool.Set mud dock and started to consolidate rig service cables.Work on Choke manifold.Weld on rat hole,Totco rigging up in pits.Organize deck, clean and dress mud pump#2.Weld on catwalk,rigging up electrical lines to hydraulic unit.Mount Totco J-box in pump room. Plan Forward:Change out crew and start two separate crews from 12 to 12.Continue rigging up drilling tools.Ship out CaBr2 on boat and start mixing kill fluid to 14.8 ppg. Remarks#2 Construction Summary#3 www.xtoenergy.com Page 2/9 Report Printed: 9/10/2013 litany Activity and Cost Summary_sfs Well Name: Middle Ground Shoal A33-14 INJ API/UWI Location Field Name Permit Number State/Province Well Configuration Type 50733200570000 TO8N-R13W-S11 Middle Ground Shoal 167-068 Alaska Directional Original KB Elevation(ft) Gr Elev(ft) KB-Ground Distance(ft) Spud Date Rig Release Date Total Depth(ftKB) 116.00 0.00 116.00 1/1/1969 Daily Operations Rpt No. Report Start Date Report End Date Operation Summary#1 9.0 6/26/2013 6/27/2013 Continue rigging up drilling tools on Platform A.All crews are on 24 hour working schedule on Platform A.Moved computer to new location and need to move cable from gathering area to office.Sling load drilling equipment from Platform C to A.Welding on catwalk,RU#7 motor.Remove stairs on Eastside F/cellar to rig floor.Plum in trip tank pump and rig Hyd unit.Off load mud products f/boat,install handrails.R/U choke line and Poor boy return line to pits.Install stairs on Westside F/rig floor to cellar. R/U bails on hook,organize tools and straighten up rig floor work bench.Install kelly hose to stand pipe,R/U man rider,dress out MP#1,Install super choke control panel.R/U rod oiler hoses on MP#1, rebuild 2"demco on MP#2,organize and pit away tools on rig floor,R/U super choke lines to manifold, hook up electrical lines.Continue building handrails,Respool tugger lines,install sensators on HP mud line. Plan forward:Continue rigging up drilling tools.Get pits ready to record volumes and start filling pits and check for leaks,prior to mixing kill fluid. Remarks#2 Construction Summary#3 Rpt No. Report Start Date Report End Date Operation Summary#1 10.0 6/27/2013 6/28/2013 Continue rigging up drilling tools,installed hydraulic hose on iron roughneck,finished bolting gas buster to choke manifold.weld legs on mud dock,worked on organizing parts connex,assisted Quadco on RN rig watch system.Installed jack mounts on#1 and#2 shaker,installed J-box F/iron roughneck. Finished R/U shakers,dressed with 150 screens,installed gun lines in pits#1 through#5,installed auger in front of shakers,welder built mounting brackets F/Quadco monitors,Assisted Quadco running cords.Checked oil and serviced all agitators,cleaned out miscelaneous debris F/inside pits,hooked up 6"return line off of gas buster,assisted welder building 4"and 6"return lines.Installed 2"circulating hose T/standpipe.Building steam IoopF/pits#7 and#8,R/U steam lines to rig.Assisted welder W/return lines.Electrician wiring in trip tank motor.Hooked up hydraulic lines on Koomey unit. Plan forward:Continue rigging up drilling lines and tools toward beginning operation.Plan on killing well on Monday. Remarks#2 Construction Summary#3 Rpt No. Report Start Date Report End Date Operation Summary#1 11.0 6/28/2013 6/29/2013 Continue rigging up drilling tools.Assisted Quadco W/installing monitors on rig floor and mud lab,R/U lifting cap and P/U slings on Hydrill,R/U 2"hose F/drill water to rig.Run sensor hoses to Choke panel and drillers console,installed pump pressure guage on drillers console,welder installed hinges on gates in pits.removed 6"baylor return.Flow line needed to be fabricated by welder,installed line guide on drilling line.Finished installing flow line,cleaned out sand and debris out of pits,filled pit#1 W/ water and flushed out pit lines,assisted Quadco W/installing pit sensors.Worked on break cooling line, worked on choke return lines,worked on HP mud lines,installed X-O on choke hose.Finished R/U 6" baylor return line,circulated through baylor brake,filling pits#7 and#8 W/FIW.Turned on steam to heat up FIW in pits. Plan forward:Continue rigging up drilling tools.Fill pits and heat water in preparation to mix kill mud. Mud engineer to be on location to insure Bromide will be mixed property. Remarks#2 Construction Summary#3 www.xtoenergy.com Page 3/9 Report Printed: 9/10/2013 �ailyii:! 11 Activity and Cost Summary_sls l GY Well Name: Middle Ground Shoal A33-14 INJ API/UWI Location Field Name Permit Number State/Province Well Configuration Type 50733200570000 TO8N-R13W-S11 Middle Ground Shoal 167-068 Alaska Directional Original KB Elevation(ft) Gr Elev(ft) KB-Ground Distance(ft) Spud Date Rig Release Date Total Depth(EKE) 116.00 0.00 116.00 j 1/1/1969 Daily Operations Rpt No. Report Start Date Report End Date Operation Summary#1 12.0 6/29/2013 6/30/2013 Continue rigging up drilling tools.Bullplugged dead end of HP mud line,R/U drain hoses in cellar,set limit switch on man rider,tested gauge on EZ-torque,replaced bulbs in pits,replaced isolation valves and check valves on steam mixer on rig floor.Continue to assist Quadco rig up in pits,welder working 6"line F/gas buster,organizing deck,received 4 sling loads,installed panic line off choke manifold. Installed shock hose F/HP mud line,stage mud products on mud dock,calibrating sensors in pits,R/U steam loop in pit#2,changed out light bulbs in cellar.Finished installing 6"gas-buster line.Started mixing the Calcium Bromide kill mud as per MI mud engineer.Installing kelly sock,circulated through HP mud line and choke manifold. Plan forward:Continue mixing kill fluid and rigging up drilling tools prior to killing well.AOGCC notified for BOPE test. Remarks#2 Construction Summary#3 Rpt No. Report Start Date Report End Date Operation Summary#1 13.0 6/30/2013 7/1/2013 Continue mixing kill_fluid and rigging up drilling tools.Build mounting plate for kelly sock,clear and organize pipe deck,rig up air slip pedal and super choke console,hang rig electrical chords under mud dock.Change gear oil in MP#1,replace oiler hose on MP#1,hang 2"fill up hose,R/U Quadco antenna,install BOP cradle,prepare misc.equipment for back load,weld bolster bars for pipe rack, work on hydraulic electric,weld mounting plate for kelly sock,relocate water supply for test pump,lay out 2 7/8"DP on pipe rack,install kelly sock.Plum water supply to test pump,continue mixing Calcium Bromide in pits,routing hose for deadline load cell,repairing hole in deck because of water leaking down on production equipment.Repair air leak in cellar. Plan forward:Continue rigging up drilling equipment.Continue building kill fluid as per MI mud engineer's instructions.Get ready to kill well as soon as kill fluid is ready and equipment is in place for forward operation.AOGCC will witness BOP test with Bob Noble when we are ready. Remarks#2 Construction Summary#3 Rpt No. Report Start Date Report End Date Operation Summary#1 14.0 7/1/2013 7/2/2013 Continue rigging up drilling tools and mixing Kill mud.Built manifold for test pump,ran hose for test pump to rig floor.Build kill mud as per MI mud engineer to 14.8 ppg.Check Koomey nitrogen bottles, trouble shoot remote panel for Accumulator,test function Baylor brake,Back load boat.Off load boat, 329 joints of 2 7/8"drill pipe,mud products and misc equipment for workover procedure.Lay out and strap 354 joints of 2 7/8"drill pipe and 9 joints of 3 1/8"drill collars.Troubleshooting HPU in cellar, remove DSA from riser.Finish repairing HPU,rig up test pump switch,assemble mud cross,R/U hoses for tubing tongs.Trouble shoot electrical problems with throttle control on MP#1.Continue mixing Calcium Bromide as per MI engineer on location.We have 160 bbls of 14.8 ppg mixed and another 100 mixed to 13.5 ppg. Plan forward:When we have 380 bbls of the kill mud mixed,kill the well as outlined in the program. Nipple down WH and nipple up BOP.Test BOP's. Remarks#2 Construction Summary#3 Rpt No. Report Start Date Report End Date Operation Summary#1 15.0 7/2/2013 7/3/2013 Build kill mud as per MI mud engineer to 14.8 ppg. M/U kill line&choke line valves on Mud Cross.Wired in&tested test pump.Install blowers on AC/DC generators.R/U hose support for Iron Rough-neck&Tubing Tong hydraulic hoses.M/U DSA and spacer spool in preparation for nipple up. Install drain valve on trip tank.Mount test chart recorder.Tested DWA motor,rotary table&mud pump rod wash&stroke counters.R/U 2"circulating hose to stand pipe.R/U hoses to kill well.Repair bleeder valve on mud pump#1.Bull-head kill pill down tubing-3000 psi @ 1 Bpm. Remarks#2 Construction Summary#3 www.xtoenergy.com Page 4/9 Report Printed: 9/10/2013 ail Activity and Cost Summa se Y tY Summary_ . t tikHC.]` Well Name: Middle Ground Shoal A33-14 INJ APINWI Location Field Name Permit Number State/Province Well Configuration Type 50733200570000 TO8N-R13W-S11 Middle Ground Shoal 167-068 Alaska Directional Original KB Elevation(ft) Gr Elev(ft) KB-Ground Distance(ft) 'Spud Date Rig Release Date Total Depth(ftKB) 116.00 0.00 116.00 1/1/1969 Deity Operations s - ;4x Rpt No. Report Start Date Report End Date Operation Summary#1 16.0 7/3/2013 7/4/2013 .BullheadJcjll pill w/14.7ppg calcium bromide to top of serfs.Monitor well(static).Circ 14.8 ppg CaBr2 up tubing x casing annulus.Started getting H2S-R/U to take returns to PTS tank.Finish killing well. Monitor well. Set BPV&nipple down well-head.N/U BOPs.Weld up targeted 90 degree elbow for choke line.Modify drilling nipple.Install rotary torque limit switch and test(OK) I Remarks#2 Construction Summary#3 Rpt No. Report Start Date Report End Date Operation Summary#1 155 17.0 7/4/2013 7/5/2013 Modify targeted 90 degree elbow for choke line.Trouble shoot lights on rig floor koomey control panel. Repair mud line pressure gauges.Install hanging line for tubing tongs.Test BOPs w/AOGCC Rep. 4' Finish modifying drilling nipple, Remarks#2 Construction Summary#3 Rpt No. Report Start Date Report End Date Operation Summary#1 18.0 7/5/2013 7/6/2013 Testing BOPs,Pull BPV-slight flow from well,Set BPV.Install drlg nipple.Pump 15 bbl weighted pill, Pull BPV, Install 2-way check,Test Blind rams,Pull 2-way check,M/U landing joint,Un-seat hanger& pull seal assembly from Pkr,Start circ hole volume to add Safe-Lube,Gained 7 bbls in pits.Shut in well.SIDPP 320-SICP 660. Returns 10.1 to 13.1ppg.Stopped to weight up more fluid.After pumping 135 bbls(17 bbls beyond bottoms up)still only getting 13.1 ppg returns.Final SIDPP 0-SICP 230 Remarks#2 Construction Summary#3 Rpt No. Report Start Date Report End Date Operation Summary#1 19.0 7/6/2013 7/7/2013 Waiting on additional mud products.Calcium Chloride,Calcium Carbinate&FloZan.Mix up 35bb1 of I 14.7ppg CaBr2&CaCl2 brine(test batch).Build 160 bbls of 14.7ppg of brine. Remarks#2 Construction Summary#3 Rpt No. Report Start Date Report End Date Operation Summary#1 20.0 7/7/2013 7/8/2013 Cont.to build 160 bbls of 14.4ppg of brine.Wait on mud products.Vis up brine and weight up w/ Safe-Carb t/14.7ppg Remarks#2 Construction Summary#3 Rpt No. Report Start Date Report End Date Operation Summary#1 21.0 7/8/2013 7/9/2013 Cont.Vis up brine and weight up w/Safe-Carb t/14.7ppg.Bullhead 120 bbls of new brine down annulus to kill well.Rev.circ.20 bbls,new brine back to pits.Monitor well.Circ to balance mud.UD 213 joints of Tbg(0.6 to 1.0 mR/hr).Hole in Tbg @ 3470', Remarks#2 Construction Summary#3 Rpt No. Report Start Date Report End Date Operation Summary#1 22.0 7/9/2013 7/10/2013 Cont.UD Tbq,Retrieved seal assembly.Test annular to 25012500 psi.Set wear ring,M/U and test Kelly,M/U milling BHA&RIH(rabbit&p/u singles)to 3,833' Remarks#2 Construction Summary#3 Rpt No. Report Start Date Report End Date Operation Summary#1 23.0 7/10/2013 7/11/2013 Cont. RIH(rabbit&p/u singles)w/Pkr mill assembly.Mill Pkr©9,610',Push to 9,656'.Circ Hi-Vis Super Sweep,Pump Dry Job.POOH for spear Remarks#2 Construction Summary#3 www.xtoenergy.com Page 5/9 Report Printed: 9/10/2013 Daily Activity and Cost Summary_sis• • If 1:Rf�1' Well Name: Middle Ground Shoal A33-14 INJ API/UWI Location Field Name Permit Number State/Province Well Configuration Type 50733200570000 TO8N-R13W-S11 Middle Ground Shoal 167-068 Alaska Directional Original KB Elevation(ft) Gr Elev(ft) ,KB-Ground Distance(ft) Spud Date Rig Release Date Total Depth(ftKB) 116.00 I 0.00 116.00 1/1/1969 Daily Operations Rpt No. Report Start Date Report End Date Operation Summary#1 24.0 7/11/2013 7/12/2013 Cont.POOH,UD milling assembly,Trouble shoot draw-works B traction motor controls&wiring.M/U Pkr spear and RIH,Spear Pkr @ 9659'w/15k,20k over-pull,Trouble shoot draw-works B traction motor controls&wiring. Remarks#2 Construction Summary#3 Rpt No. Report Start Date Report End Date Operation Summary#1 25.0 7/12/2013 7/13/2013 Pump dry job,POOH&LID fish(retrieved all 36'),Test BOPs,Change out generator#1,3&4 contacts in DC panel.RIH w/4-1/8"Junk Mill assembly for clean out. Remarks#2 Construction Summary#3 Rpt No. Report Start Date Report End Date Operation Summary#1 26.0 7/13/2013 7/14/2013 Cont.RIH w/4-1/8"Junk Mill,Clean out scale f/9610'-t/10,169'(Mill quit making hole),POOH, Remarks#2 Construction Summary#3 Rpt No. Report Start Date Report End Date Operation Summary#1 27.0 7/14/2013 7/15/2013 Cont.POOH w/clean out assembly(Mill in good condition)Cup full of metal junk).Service rig,RIH w/5" casing scraper t/9580',Circ.Hi-Vis Sweep,Pump dry job.Drop 1-1/8"rabbit,POOH. Retrieve rabbit. UD scraper BHA. Remarks#2 Construction Summary#3 Rpt No. Report Start Date Report End Date Operation Summary#1 28.0 7/15/2013 7/16/2013 M/U tail pipe&Mod.D Pkr assembly.RIH on DP.Set Mod.D Tripoint Pkr @ 9,525',WLEG @ 9,621', Test Pkr to 2000 psi for 30 minutes.Un-sting from Pkr.L/D DP Remarks#2 Construction Summary#3 Rpt No. Report Start Date Report End Date Operation Summary#1 29.0 7/16/2013 7/17/2013 Cont.UD drilipipe.Break&UD Kelly,Pull wear ring, M/U Pkr seal assembly and run completion Tbg. • Remarks#2 •'( -)ii Construction Summary#3 II"1 1t/ Rpt No. Report Start Date Report End Date Operation Summary#1 30.0 7/17/2013 7/18/2013 Cont.P/U completion Tbg,Space out&M/U Hanger,Pickle Tbg&reverse out to PTS tank,Spot 500 gal pickle acid,Stab in seal assembly&land hanger,Bullhead acid into formation,3200 psi©3 bpm w/14.7 brine Remarks#2 Construction Summary#3 Rpt No. Report Start Date Report End Date Operation Summary#1 31.0 7/18/2013 7/19/2013 Monitor well(static).Test annulus t/2000 psi(OK).Flush BOP equipment&mud lines.Set BPV,N/D .BOPS, Remarks#2 Construction Summary#3 . Rpt No. Report Start Date Report End Date Operation Summary#1 32.0 7/19/2013 7/20/2013 N/U Wellhead,Test Void&Wellhead V 5000 psi.Pull 2-way check valve,R/U slickline,Attempt to set plug in XITNlpple(( o goodr Remarks#2 Construction Summary#3 www.xtoenergy.com Page 6/9 Report Printed: 9/10/2013 tY litaily Activity and Cost Summary_sls • t:N k:EiL.Y Well Name: Middle Ground Shoal A33-14 INJ API/UWI Location Field Name Pernit Number State/Province Well Configuration Type 50733200570000 TO8N-R13W-S11 Middle Ground Shoal 167-068 Alaska Directional Original KB Elevation(ft) Gr Elev(ft) KB-Ground Distance(ft) Spud Date Rig Release Date Total Depth(ftKB) 116.00 0.00 116.00 1/1/1969 Daily Operations Rpt No. Report Start Date Report End Date Operation Summary#1 33.0 7/20/2013 7/21/2013 Test Tbg U 4000 psi(Good test).RIH to open Sliding Sleeve @ 9504',stopped at 9470'.POOH.RIH slick.stopped at 9450',attempt to work down hole,gained excess drag,POOH,no tool string.Thread line thru pack-off&re-head, RIH w/impression block,Tagged @ 9,275',POOH,Wire in hole,RIH w/ wire finder,Cont.fishing for wire and tools Remarks#2 Construction Summary#3 Rpt No. Report Start Date Report End Date Operation Summary#1 34.0 7/21/2013 7/22/2013 Cont.fishing for wire and tools using wire grabs of various designs on slick-line @ 9250,Cut a total of 6000'of bad wire at various times.Had 100#over-pull on POOH up to @ 8100'lost excess wt,RIH, work tools-no excess wt.Mud very thick at 9200'tools moving slowly. Get e-line dump bailer to spot fluid to re-hydrate brine, Coil tubing to show up on thursday Remarks#2 Construction Summary#3 Rpt No. Report Start Date Report End Date Operation Summary#1 35.0 7/22/2013 7/23/2013 _Strip_6g04'ofDawir> =Cont.fishing for wire and tools using wire grabs of various designs on slick-line 9250,Could not grab fish.Run Lead Impression Block-no impression,Strip 1500'of bad wire, Dis-continue slickline work,slickline becoming deteriorated and concerned about losing more tools,R/D slickline,Prep to skid rig,Cleaning rig Remarks#2 Construction Summary#3 Rpt No. Report Start Date Report End Date Operation Summary#1 36.0 7/23/2013 7/24/2013 Finished skidding rig on Platform C.Continued cleaning rig on Platform A,Getting ready to skid rig off of hole and making preparations for Coil Tubing unit from Schlumberger.Sent one of the rig crews to shore.Working crew from 6AM to 6PM. Plan forward:Skid rig off of hole,Brendon Webb of Schlumberger said that the 1 1/2"coil unit will be ready to ship out on Thursday morning. Need to send welder and helper over to Platform C to finish installing hand rails. Remarks#2 Construction Summary#3 Rpt No. Report Start Date Report End Date Operation Summary#1 37.0 7/24/2013 7/25/2013 Skid the rig off the well and stop in the center of platform.Waiting for Schlumberger coil tubing unit which will be loaded on the first available work boat at 5:00 PM.The operator and 3 roustabouts will arrive on the evening chopper.The crew is down to 6 on the crew to include,tool pusher,2 drillers,one roustabout,crane operator,and electrician.They will work as needed during the operation. Plan ahead:Receive the coil tubing unit and set it up over the well.Test the stack and start the plan forward. Remarks#2 Construction Summary#3 Rpt No. Report Start Date Report End Date Operation Summary#1 38.0 7/25/2013 7/26/2013 Finish skidding rig so beaver slide sits down.R?D jacks.Clean back deck,install storm clamps, organize top deck to prepare for coil tubing.Store jacking units in cellar.Off load coil tubing unit from work boat.Organize coil tubing on deck with Schlumberger crew directing placement of tools.The remaining tools for the coil tubing unit will be on this morning boat to be loaded at 07:00 AM. Plan forward:Finish moving in all coil tubing equipment and placing the same while being directed by Schlumberger crew.Remove well cap and nipple up tubing BOP,lubricator and injector head.Test BOP and all other equipment accordingly.Test witness was waived by Jim Regg of AOGCC. Remarks#2 Construction Summary#3 www.xtoenergy.com Page 7/9 Report Printed: 9/10/2013 • t; �aily Activity and Cost Summary_se 41.11(,l' Well Name: Middle Ground Shoal A33-14 INJ API/UWI Location Field Name Permit Number State/Province Well Configuration Type 50733200570000 TO8N-R13W-S11 Middle Ground Shoal 167-068 Alaska Directional Original KB Elevation(ft) Gr Elev(ft) KB-Ground Distance(ft) Spud Date Rig Release Date Total Depth(ftKB) 116.00 0.00 116.00 1/1/1969 Daily Operations Rpt No. Report Start Date Report End Date Operation Summary#1 39.0 7/26/2013 7/27/2013 Finish off loading the remainder of the equipment off of the work boat.Place the equipment on deck according to the Schlumberger crew directions.Rigged up the coil tubing unit over the well and test the BOP's.Test was good.We only have one operator,so the crew will start the operation in the morning. Plan forward:Pick up wash nozzle and the dean out assembly,run into the hole and clean out tubing by pumping out the kill fluid with FIW,taking returns in the pits.Clean out tubing to the fish and then POOH with coil tubing unit and lay down BHA and pick up fishing assembly and TIH with assembly under the direction of the Weatherford fishing representative.Fish out wireline. Remarks#2 Construction Summary#3 Rpt No. Report Start Date Report End Date Operation Summary#1 40.0 7/27/2013 7/28/2013 Finish P/U coil tubing M/U washing assembly.RIH and curculate and wash down to 9558".CBU and POOH.—R/D coil head and shut well.R/D washing assembly.Fog stayed around rig all day,so the helicopter was unable to bring out Weatherford.The coil tubing crew only have one crew and they worked 12 hours and shut down untill morning.Brought out Weatherford with his tools and the mud products needed for the packer fluid next to the packer with the work boat.We will start fishing at 06:00 hours.While the coil tubing crew was washing down,the skeleton crew that we have,covered the drillers console,draw works and iron roughneck with poly.They cleaned the East side drains and anti siezed all BOP bolts.Placed parts house and injected dirty returns fluid. Forward plans: Pick up fishing assembly and go in and fish out the slick line.POOH with fish and lay down the same.TI fish is ofh7e,lay down fishing assembly and P/U nozzle assembly and RIH to clean out to 10,000'.Close coil tubing annulus and attempt toestablish injection into the perforations at 3 bpm.If the 3bpm cannot be attained,prepare and mix 500 gal of 10%HCL acid.Follow procedure and R/U slick line to open sliding sleeve to remove annulus kill fluid and replace with weighted packer fluid and FIW packer fluid.After finishing procedures,R/D slick line and coil tubing unit.Finish work over procedure. Remarks#2 Construction Summary#3 Rpt No. Report Start Date Report End Date Operation Summary#1 41.0 7/28/2013 7/29/2013 Pick up fishing assembly with spear and TIH to recover fish.Caught fish and started pulling out to restriction at the sliding sleeve.Was not able to pull through,the fish went back down with no problem. Pulling up to the sleeve,the fish would not go through.Worked it and set the jars of 7 times before it came loose.POOH and there was no fish.Looking at the spear we decided that there was no wire and we needed to go in with a overshot.Discussed the problem with XTO engineer and secided that this would be the best option.TIH with overshot assembly and attached fish.POOH with fish and laid down_ same with fishing assembly. Plan forward:Pick up slick line equipment and have it ready for the operator when he gets here on the first helicopter.Pick up sliding sleeve shifting tool and TIH to open.Reverse out the kill fluid in the annulus with FIW and then place weighted packer fliud,followed with packer fluid in the FIW.TIH with tool and close sliding sleeve.Pressure test to 2,400 psi for 30 minutes and chart.R/D slick line and R/U coil tubing with clean out assembly and TIH to clean out to 10,000'.Close annulus and establish a 3 bpm injection rate.If injection rate cannot be established,do a acid wash and then try a injection rate. Once this is done follow procedure and move the equipment off of the platform. Remarks#2 Construction Summary#3 www.xtoenergy.com Page 8/9 Report Printed: 9/10/2013 taily Activity and Cost Summary_se • ?farl3i: Gy Well Name: Middle Ground Shoal A33-14 INJ API/UWI Location Field Name Permit Number State/Province Well Configuration Type 50733200570000 TO8N-R13W-S11 Middle Ground Shoal 167-068 Alaska Directional Original KB Elevation(ft) Gr Elev(ft) KB-Ground Distance(ft) Spud Date Rig Release Date Total Depth(ftKB) 116.00 0.00 116.00 1/1/1969 Daily Operations ff. ...... . . Rpt No. Report Start Date Report End Date Operation Summary#1 42.0 7/29/2013 7/30/2013 Fog all day and we were not able to fly helicopter.Brought out tools and a Weatherford hand on a work boat to slide the sleeve open.The boat arrived at 21:30 and we started rigging up the tools to TIH and open sliding sleeve.Opened the sleeve and didn't see any change in flow on the tubing side and did not see any suction on the annulus side.Talked to XTO engineer and decided to pressure up to 1000 psi on the annulus.It took 2.8 barrels and went to 1200 psi and bled off to 100 psi in 30 minutes.Decided to bring the pressure up to 2,000 psi and close off and let it to continue bleeding off.With coil tubing out of the hole we are rigging down tools and rigging up washing nozzels to trip in the hole and clean out to 10,000'so we can pressure up to injection rate after hole is clean. Plan forward:Continue working the annulus with pressuring up to 2,000 psi and letting it bleed off until the kill fluid in the annulus it completely replaced by the FIW.When it has been cleaned out,replace with packer fliud,close sliding sleeve.Get an injection rate,and finish completion. Remarks#2 Construction Summary#3 Rpt No. Report Start Date Report End Date Operation Summary#1 43.0 7/30/2013 7/31/2013 Continue to pressure up on the annulus to break out the kill fluid.Pressured up to 2,000 psi with no results.P/U nozzels for coil tubing and washed down to 10,172'.Could not go any deeper due to an obstruction in the hole.Circulated clean and then POOH to sliding sleeve and closed rams and pressured up to 3,000 psi.Returns started coming out of annulus.Continued pumping 60 bbls before the returns stopped and wi started to inject into the formation and pressure dropped to 1,900 psi. Stopped pumping and POOH with coil tubing.Discussed plan forward with XTO engineer and decided to pump with rig pumps down the tubing and try to get returns.Started pumping with no returns and stopped at 1,700 psi.Decided to pump down annulus.Pumped at a rate of 1.5 bpm and got returns. cleaned out annulus and continued pumping for 3 circulations. Plan forward: P/U tools to close sliding sleeve with coil tubing.TIH with coil tubing.Pump down annulus with packer fluid and close sliding sleeve when finished.Pressure up on annulus for 30 minutes to make sure sleeve is closed.POOH with tool and change out with nozzels and RIH to bottom at 10,172'and pump BU.Close rams and try to establish injection rate at 3 bpm.POOH and R/D coil tubing,release rig from well. Remarks#2 Construction Summary#3 Rpt No. Report Start Date Report End Date Operation Summary#1 I/ 44.0 7/31/2013 8/1/2013 TIH with sliding sleeve tool to close.Pumped 3 bbls 14 ppb packer fluid and 90 bbls packer fluid with A FIW and corrosion inhibitor down the tubing-casing annulus.Close the sliding sleeve and test_to2_40Q_. psi for 30 minutes.Test was good(lost 31_psi).POOH to change out tool for nozzle to wash the tubing down to 10,174'.TIH while washing tubing.When on bottom,circulate until clean fluid is all around.Pull tubing up to 10,000'and close the coil tubing annular rams after placing 10%HCI down to the end of the coil tubing.Inject the HCI and follow with 10 bbls FIW to inject the HCI.Pull coil tubing out of the well and lay down BHA.Rig down coil tubing unit and get ready to load on work boat. Plan Forward:Rig down coil tubing.Get ready to load work boat at midnight.Load work boat and send equipment to shore.Tum well over to production. Remarks#2 Construction Summary#3 www.xtoenergy.com Page 919 Report Printed: 9/10/2013 • 0 Schwartz, Guy L (DOA) From: Adeyeye, Ajibola <Ajibola_Adeyeye@xtoenergy.com> Sent: Monday, August 05, 2013 8:23 AM To: Regg, James B (DOA); Schwartz, Guy L (DOA); Wallace, Chris D (DOA) Cc: Griffith, Scott; Duggin, Greg Subject: XTO Energy- A33-14 (1670680) Rate and Pressure Monitoring June 2013 AIO # 9.008 Attachments: A33-14 Rate and Pressure Monitoring JUNE 2013 (AIO 9.008).xisx Jim, Guy, Chris Attached is June 2013 injection and wellhead pressure monitoring report for Middle Ground Shoal A33-14 required by Administrative Approval AIO No. 9.008. Well workover to replace tubing and fix communication between the tubing and tubing —casing annulus just concluded. Tubing -casing annulus is being monitored for workover success; post injection mechanical integrity test will be scheduled with the other wells on platform C Regards Ajibola (Bola) A. Adeyeye Operations Engineer —Western Division XTO Energy —Subsidiary of ExxonMobil Office: 303-397-3606 Cell: 720-539-1660 HED AUG 0 6 2013 ,ktC—, S A-73>3-14- 1&7066c, Regg, James B (DOA) From: Alaska_Drilling@xtoenergy.com Sent: Tuesday, July 09, 2013 4:06 PM To: Regg, James B (DOA) Cc: DOA AOGCC Prudhoe Bay Subject: RE: Reporting use of BOPs i We tested the annular preventer to 250/2500 psi. Today was the fist time we have been out of the hole since we shut in the well on the 5th. We picked up and tested the Kelly to 250/3500 psi. Regards, Joe Steiner Drlg Supervisor XTO Energy Platform A 907-776-2500 "Regg, James B (DOA)" <iim.regg(&alaska.gov> 07/06/2013 12:07 PM Please respond to "Regg, James B (DOA)" <iim.reggCa)alaska.gov> Yes you are. Sent from Samsung Mobile To Alaska Drilling/KEN/CTOC, DOA AOGCC Prudhoe Bay <doa.aogcc.orudhoe.bay0alaska.gov> cc Subject RE: Reporting use of BOPs -------- Original message -------- From: Alaska Drilling_a xtoenerg Date: 07/06/2013 12:00 PM (GMT -09:00) To: DOA AOGCC Prudhoe Bay<doa.aogcc.prudhoe.bayna,alaska. og_v> Subject: Reporting use of BOPs AOGCC BOPE use to prevent flow of fluids Time 7/5/13 1300HR Well # A33-14 1 'Platform A PTD # 1670680 Rig # Platform A Operator Contact / Joe Steiner XTO Energy 907-776-2500 Summary; After killing the well and nippling up BOPs and completing or initial BOP test on 7-5-13 for this well we un -seated the Tbg Hanger and pulled the seal assembly from the permanent packer. At that time we started to circulate a hole volume prior to laying down the tubing. The returning brine was coming back under weight and upon seeing a gain in pit volume we stopped pumping, checked flow(slight flow from well) and shut in well using the annular preventer @ 1300 hrs on 7-5-13. We are currently building more brine to kill the well. After killing the well and circulating an additional hole volume we will lay down the tubing. Are we required to re -test the annular preventer on our next trip out of the hole? Regards, Joe Steiner Drlg Supervisor XTO Energy Platform A Alaska drilling(o)-xtoenergy.com 907-776-2500 P-6 /676630 Regg, James B (DOA From: Regg, James B (DOA) i� f -7 g<< Sent: Saturday, July 06, 2013 12:08 PM To: Alaska_Drilling@xtoenergy.com; DOA AOGCC Prudhoe Bay Subject: RE: Reporting use of BOPs Yes you are. Sent from Samsung Mobile -------- Original message -------- From: Alaska_Drillin xtoenergy.com Date: 07/06/2013 12:00 PM (GMT -09:00) To: DOA AOGCC Prudhoe Bay<doa.aogcc.prudhoe.baykalaska.gov> Subject: Reporting use of BOPs AOGCC BOPE use to prevent flow of fluids Time 7/5/13 1300HR Well # A33-14 ' Platform A PTD # 1670680 Rig # Platform A Operator Contact / Joe Steiner XTO Energy 907-776-2500 Summary; After killing the well and nippling up BOPs and completing or initial BOP test on 7-5-13 for this well we un -seated the Tbg Hanger and pulled the seal assembly from the permanent packer. At that time we started to circulate a hole volume prior to laying down the tubing. The returning brine was coming back under weight and upon seeing a gain in pit volume we stopped pumping, checked flow(slight flow from well) and shut in well using the annular prevent r @ 1300 hrs on 7-5-13. We are currently building more brine to kill the well. After killing the well and circulating an additional hole volume we will lay down the tubing. Are we required to re -test the annular preventer on our next trip out of the hole? Regards, Joe Steiner Drlg Supervisor XTO Energy Platform A Alaska drillinq(o-)-xtoenergy.com 907-776-2500 MISC. INSPECTIONS: STATE OF ALASKA Location Gen.: P Housekeeping: OIL AND GAS CONSERVATION COMMISSION Reviewed By: P.I. Supry LG S A-33._ 1/4 BOPE Test Report P Comm Contractor/Rig No.: All American Oil XTOA PTD#: 1670680 ' DATE: 7/5/2013 Inspector Bob Noble Insp Source Operator: XTO ENERGY INC Operator Rep: Joe Steiner Rig Rep: Ross Grubb Inspector Type Operation: WRKOV Rams: Annular: Valves: Inspection No: bopRCN130707071056 Type Test: INIT Test Pressure: 250/3500 , 250/2500 - 250/3500 - Related Insp No: P MISC. INSPECTIONS: TEST DATA MUD SYSTEM: P/F Location Gen.: P Housekeeping: P PTD On Location P Standing Order Posted P Well Sign P Dr]. Rig P Hazard Sec. P Misc NA TEST DATA MUD SYSTEM: BOP STACK: Visual Alarm Trip Tank P P Pit Level Indicators P P Flow Indicator P P Meth Gas Detector P P - H2S Gas Detector P P MS Misc NA NA ACCUMULATOR SYSTEM: BOP STACK: Time/Pressure P/F System Pressure 2975 - P Pressure After Closure - 1.675 P _ 200 PSI Attained 44 P Full Pressure Attained 180 P Blind Switch Covers: all stations P Nitgn. Bottles (avg): -4 na, 1850_ -.--P_ 13-5/8 ACC Misc 0 NA FLOOR SAFTY VALVES: BOP STACK: Quantity P/F Quantity Size P/F Upper Kelly 1 NT Stripper 0 none--___-_ - NA Lower Kelly --_ INT • Annular Preventer 1 13-5/8 FP ' Ball Type 1 P #1 Rams 1 2 3/8" x 3 1/2 FP ' Inside BOP 1 P _ #2 Rams l blinds FP ' FSV Misc 0 NA #3 Rams 0 none NA #4 Rams 0 none NA #5 Rams 0 none NA #6 Rams - 0 none _ NA Choke Ln. Valves 1 3-1/8 P HCR Valves 1 3-1/8 __- P Kill Line Valves 2 2 1/16 P Check Valve 0 none NA BOP Misc 0 none NA CHOKE MANIFOLD: Quantity P/F No. Valves 14 P Manual Chokes 1 P Hydraulic Chokes 1 P - CH Misc 0 NA INSIDE REEL VALVES: (Valid for Coil Rigs Only) Quantity P/F Inside Reel Valves Number of Failures: 3 Test Results Test Time 16 Remarks: Rams and bag were tested against 2 3/8" and 2 7/8" test joints. Rams and bag tested good with the 2 7/8" Rams had to be cycled to pass 2 3/8". Pressure had to be increased -to pass bag on 2 3/8". Blinds had to be cycled to pass. Upper and lower kelly were not rigged up and not tested. I told Joe he needed to let us know and est them before using them. They were going to remove BPV and install 2 -way check to test blinds. When BPV was removed, a small amount of pressure was noted and they had to kill the well again before setting 2 -way check. Ir „, � T„ j 4” sv THE STATE Alaska i and as ®f l 1 1 1 Conservation Commission 9 - a =_ GOVERNOR SEAN PARNELL ,� { 333 West Seventh Avenue OJT Anchorage, Alaska 99501 -3572 ALAS Main: 907.279.1433 Fax: 907.276.7542 Sandra Haggard Regulatory Analyst �/ XTO Energy /67 06 9127 Jamaica Street Englewood, CO 80112 Re: Middle Ground Shaol Field, E, F, and G Pools, MGS A33 -14 Sundry Number: 313 -013 Dear Ms. Haggard: SCANNED MAR o 6 2413 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, / 9 7 L 7 / 6 „ .... _ Cathy ' . roerste Chair DATED this I1' day of February, 2013. Encl. • RECEIVED . STATE OF ALASKA � 1 5 2 13 ALASKA OIL AND GAS CONSERVATION COMMISSION �.. 71 . Z I APPLICATION FOR SUNDRY APPROVALS A 20 AAC 25.280 1. Type of Request: Abandon ❑ Plug for Redrill ❑ Perforate New Pool ❑ Repair Well ©• Change Approved Program ❑ Suspend ❑ Plug Perforations ❑ Perforate ❑ Pull Tubing ©• Time Extension ❑ Operations Shutdown ❑ Re -enter Susp. Well ❑ Stimulate ❑ Alter Casing ❑ Other: ❑ 2. Operator Name: XTO Energy - 4. Current Well Class: 5. Permit to Drill Number: Exploratory ❑ Development ❑ 167-068 • 3. Address: Stratigraphic ❑ Service El • fi. API Number: i' 9127 S Jamaica Street, Englewood, CO 80112 50- 733 - 20057- 00 dill 2 7. If perforating: 8. Well Name and Number. What Regulation or Conservation Order govems well spacing in this pool? Will planned perforations require a spacing exception? Yes ❑ No ❑ Middle Ground Shoal A33 -14 • 9. Property Designation (Lease Number): 10. Field /Pool(s): ADL 187566 MGS E, F, G Pools 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): ' 10,555 8,816 - 10,432 8,704 N/A N/A Casing Length Size MD TVD Burst Collapse Structural Conductor Surface 1,890' 10 -3/4" 1,890' 1,763' 3,130 psi 1,580 psi Intermediate 10,531' 7" 10,531' 8,794' 6,340 psi 3,830 psi Production 10,432' 5" 10,432' 8,705' 10,140 psi 10,490 psi Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 9,715 - 10,419 • 8,073 - 8,693 2 -3/8" L -80 9,649 Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): Baker DB Perm Pkr, No SSSV' Packer: 9,610' (MD), 7,982' (TVD) 12. Attachments: Description Summary of Proposal p • 13. Well Class after proposed work: Detailed Operations Program Q BOP Sketch El . Exploratory ❑ Stratigraphic ❑ Development ❑ Service s • 14. Estimated Date for 3/15/2013 15. Well Status after proposed work: Commencing Operations: Oil ❑ 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 Sandra Haggard Email Sandra Haggardaxtoenerqv.com Printed Name Sandra Haggard Title Regulatory Analyst Signature Phone 303 - 397 -3672 Date January 14,2013 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 31 ^ J Ot � Plug Integrity ❑ BOP Test LYJ Mechanical Integrity Test Location Clearance ❑ Other: 1.- 3 5OU / S P le - 7 - 5 1 ---- 1-4.0 s s ,mil' 114 Cr— IA // 2_300 / Si✓ hn a ..L4 ... S -b,_ (; L.c� .1 K_j . 4 ,24.47 -'1 Gh cq,, t2 GGar•<' (41( /0 7 j nsn a ref ca.t 1,3 Spacing Exception Required? Yes ❑ No Subsequent Form Required: /Q — Lrd L( - I RE3DMS FEB 15 2013 APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: _ ` — ( 3 0 2 ?./..T • /, Submit Form and �vv 'b 0R F 8 ( e1 4 /. 1!2) Approved plication is valid for 12 months from the date of approval, , q a _ ments in Duplicate , `�` • • Aro RECEIVED JAN 15 2013 ENERGY AOGCC January 14, 2013 Alaska Oil and Gas Conservation Commission Attn: John Norman, Commissioner 333 W. 7 Ave., Suite 100 Anchorage, Alaska 99501 -3539 RE: Form 10 -403, request for Sundry Approval Objective: Pull Tubing and repair well Middle Ground Shoal #A33 -14 Water Injection Well Middle Ground Shoal Field, E, F & G Oil Pool Cook Inlet, Alaska API 50- 733 -20057 XTO Energy Inc. herby submits its Application for Sundry Approvals to pull tubing and repair well. Enclosed are the following attachments: 1. Form 10 -403 Application for Sundry Approval 2. Cover Page 3. Summary Page 4. Injection Plot 5. Rate & Pressure Monitoring Plots for Injection Waiver 6. Deviation Survey 7. Job Procedure 8. Current Wellbore Diagram 9. Proposed Wellbore Diagram 10. Wellhead Schematic 11. BOP Schematic If you require additional information, please contact me at (303) 397 -3672 Sincerely, c -j:7,14t- Sandra M. Haggard, Regulatory Analyst Copy To: Alec Bridge, Operations Engineer @ (303) 397 -3608 XTO Energy Inc. • P.O. Box 6501 • Englewood, CO 80155 • 9127 S. Jamaica St. • Englewood, CO 80112 • (303) 397 -3600 • Fax: (303) 397 -3899 An ExxonMobil Subsidiary • • TO RECEIVED GD ENERGY JAN 15 2013 AOGCC January 9, 2013 To: John Norman Guy Schwartz Victoria Ferguson CC: Scott Griffith Scott Landon Romeo Perez From: Alec Bridge Re: MGS A33 -14 WIW (167 -068) Cook Inlet, Platform A Workover to Eliminate Tubing- Casing Pressure Communication OBJECTIVE: The objective of XTO's proposed workover for the MGS A33 -14 WIW is to eliminate the pressure communication between the tubing and casing. The well experienced a tubing failure in August, 2010. The AOGCC granted XTO an injection waiver in September, 2010, that allowed XTO to continue injecting under certain conditions. The tubing and packer in the well were installed in 2000. Both the tubing and packer will be removed and replaced with new equipment. XTO will perform a MIT after replacing the tubing and packer and then resume normal injection operations. WELL HISTORY: Shell drilled and completed the MGS A33 -14 WIW in 1967 as a producer in the East Flank Hemlock (GN -HZ). The well's initial production rates were 2,177 BOPD, 11 BWPD, and 830 MCFPD. Production quickly declined to uneconomic volumes. In 1969 Shell converted the well from a producing well to a water -flood injector well. The well developed a leak in the 7" production casing in 1984, and Shell repaired the casing leak by squeezing it with cement. During the same workover, Shell installed a 5" liner over all of the perforations and selectively recompleted certain intervals to control water injection and to minimize water production in the adjacent producing wells. XTO acquired the well in 1998. The well experienced both a tubing failure and a casing failure in 1999. During the subsequent workover in 2000, XTO ran a 5" tie -back liner to surface and replaced the tubing, packer, and wellhead. In August, 2010, XTO noted pressure on the tubing- casing annulus, which indicated a tubing failure. XTO shut in the well until September, 2010, when the AOGCC granted XTO a waiver to continue injecting and to defer repairing the well. The current injection rate is 500 BWIPD at 3,500 psig. MISCELLANEOUS: The AOGCC has granted XTO a waiver since 1999 concerning the BOPE stack since the rig's sub structure can only fit a double ram configuration (BOP schematic is attached) and not a triple ram configuration. XTO was grandfathered a variance due extensive knowledge of the mature Middle Ground Shoal Field and due to depleted reservoir pressure. XTO is requesting the same variance for this workover. si p 4.3641) / s L The anticipated start date for workover operations is March, 2013. Please contact me at 303 - 397 -3608 with any qu tions or concerns. Sincerely, 0 10, e - 6 /1;_etr Alec Bridge g Operations Engineer • • ft GY WORKOVER SUMMARY FOR MGS A33 -14 WIW Scope of work: Eliminate tubing- casing pressure communication by pulling tubing and packer and installing new tubing and packer. Current Well Status: 500 BWIPD & 3,500 psig injection pressure Well Info: See attached procedure and deviation survey. BHP & Kill Weight: BHP = 6,000 psi: (8.4 ppg FIW) x (8,379' mid perf TVD) x (0.052) + (2,350 psi SITP) = 6,010 psi (Assumes fluid at surface) Kill Weight: 6,000 psi = (0.052) x (8,073' top perf TVD) x (W, ppg) W= 14.3ppg 14.3 ppg + 0.5 ppg = 14.8 ppg kill fluid mud recipe: 1 bbl 14.8 ppg CaBr2 fluid = 360 lbs CaBr2 + 0.7487 bbl 8.4 ppg FIW Based upon surveys of offset producers, the East Flank Hemlock BHP is 5,000 - 6,000 psi. As seen in the attached Injection Rate & Pressure Monitoring Plot, the tubing pressure bled down to and stabilized at 2,350 psig when XTO ceased injecting for maintenance of the water flood injection pump (December, 2011). The tubing string was filled with 8.4 ppg FIW. L 6 < < i4_ MIT Info: The well has had an Injection Waiver 9.008 since September, 2010 and no MITs have been performed since then. As seen in the Injection Rate & Pressure Monitoring Plot, the well has good integrity on the 5" casing, 7" casing, and 10 -3/4" casing. BOPE Ram Configuration: Variable Pipe Rams (VPRs) for 2y8" to 2 -7/8" pipe (procedure and BOPE schematic are attached). Workover Rig: XTO's derrick is a permanent rig on Platform A. Requested Waiver: The AOGCC has granted XTO a waiver since 1999 concerning the BOPE stack since the rig's sub structure can only fit a double ram configuration (BOP schematic is attached) and not a triple ram configuration. XTO was grandfathered a variance due extensive knowledge of the mature Middle Ground Shoal Field and due to depleted reservoir pressure. XTO is requesting the same variance for this workover. �qU«� ► _ frthe P t 3ov° p XTO Energy Contacts: y 4- L . t L • `3 Operations Engineer: Alec Bridge, 303 - 397 -3608, alexander_bridge @ xtoenergy.com Engineering Manager: Romeo Perez, 303 - 397 -3603, romeo_perez @xtoenergy.com Superintendent: Scott Griffith, 907 - 776 -2506, scott_griffith@xtoenergy.com • • /TO ERGY MASP FOR MGS A33 -14 WIW Current Well Status: 500 BWIPD & 3,500 psig injection pressure. This well has been a waterflood injection well since 1969. It is unlikely that the well will kick after being on injection for over 40 years; however, for safety purposes, a 10% oil cut will be used to calculate the MASP. MASP: Top Perf TVD = 8,073' Mid Perf TVD = 8,379' SITP = 2,350 psi ✓ 8.4 ppg FIW = 0.437 psi /ft 34° API oil = 0.370 psi /ft BHP = (0.437 psi /ft) x (8,379') + (2,350 psi) = 6,012 psi ' Ph = (0.1) x (0.370 psi /ft) x (8,073') + (0.9) x (0.437 psi /ft) x (8,073') = 3,474 psi MASP = 6,012 psi — 3,474 psi = 2,538 ps Alec Bridge Operations Engineer BBL • A33 -14 INJ HEMLOCK 1,000 - 1 900 - 800 - 700 - 600 - I \P 500 lt 400 - 300 - 200 - 100 - 0 JII ` , 12/6/09 4/1 7/1 10/1 1/1 4/1 7/1 10/1 1/1 4/1 7/1 12/5/12 — Water Inj PSI A33 -14 INJ HEMLOCK Hrs Dn 3,750 •30 3,500 - . 28 3,250 - • 26 3,000 - - I- - • 24 2,750 - 22 PT 2,500 - - - - • zo 2,250 ' 18 2,000 - - - -16 - 1,750 - - - -14 - 1,500 - - -12 1,250 - - -10 a - 1,000 - - -8 - 750 - - -- - - -6 a - - 500- - ... - -a. -4 250 - - - - -2 0 - - - -0 12 /6/09 4/1 7/1 10/1 1/1 4/1 7/1 10/1 1/1 4/1 7/1 12/5/12 — Casing Pressure Tubing Pressure —Annulus Pressure - - SurfaceCasingPressure Inte XTO Energy - A33 -14 (1670680) Rate and Pressure Monitoring Administrative Approval AIO No. 9.008 5000 - TBG Annulus [psig] WH Injection [psig] 1000 — .-- Injection Rate [bbl /d] Surface Casing [psig] 4500 900 . —9— 7" Intermed [psig] = 4000 800 w? cn ca co - a z 0 3500 _ ,^ .. „ 700 3000 ^fi� r j 600 f0 a h , � I' Ili - cu F2 2500 t ap,,, , , .I � M i. c c ` '� i / 5 00 < 1 it I I - F- • ,I M il .. a...1 2000 4 00 1500 • 300 • • - •I 1000 - 200 500 • • 100 • 0 .r_s _ _ —. 0 ^^ ^N NN ^N ^ N ^N ^N N __ NN ^N ^^ NN ^ NI' NI' ^ti �ti < NI' ^ti Nti Nei' Nei' A � 1, A 'P A. •P A A A A , (P \ti \ 1 , N cP ti o \ , L O \ti ti P � A I s? �,tio XTO Energy - A33 -14 (1670680) Rate and Pressure Monitoring Administrative Approval AIO No. 9.008 5,000 —A-- TBG Annulus [psig] 1,000 — — Injection [psig] - 4,500 —o— Injection Rate [bbl /d] 900 Surface Casing [psig] m 8 m C 4,000 — -7" Intermed [psig] Cl) N re Z 3,500 700 06 • o N V - d m a = 3,000 600 m m - 08 E c 2,500 500 E c c - o6 c m Q c) rn 2,000 400 t H _ to 1,500 300 I 1,000 200 500 100 • o $ -n r n r I • I • I • I • I 0 `1 0 \ , L o ,yo \ ti o \ ,� o \ti \ , L o \ �o \ ,o \ ,� o \ � o \ , ti o \ti \ , L o \ , L o \ , L o o \ o \r .& o \ A ' \ ^ \N \ma \ ^ \ ,� a, \,� \ \ ,�c, \ ,� � \ ,� o, \ �. • • A Platform, Well A33 -14 WIW INTEQ Alaska State Plane Coordinates Measured Angle Azimuth TVD -RKB ND X Y N / -S E / -W DLS Vert. Sec SVY# Depth deg deg ft Subsea ft j ft ft ft deg /100 ft ft Tie -In 0.00 0.00 0.00 0.00 - 116.00 232832.80 2485777.86 0.00 0.00 0.00 0.00 1 75.00 0.50 340.00 75.00 -41.00 232832.70 2485778.17 0.31 -0.11 0.67 0.30 2 100.00 0.42 335.00 100.00 -16.00 232832.62 2485778.36 0.49 -0.19 0.36 0.48 3 125.00 0.33 345.00 125.00 9.00 232832.57 2485778.51 0.65 -0.25 0.44 0.63 4 150.00 0.25 352.00 150.00 34.00 232832.55 2485778.64 0.77 -0.27 0.35 0.74 5 175.00 0.42 329.00 175.00 1 59.00 232832.50 i 2485778.77 0.90 -0.33 0.85 0.87 6 200.00 0.75 307.00 200.00 84.00 232832.32 1 2485778.95 1.08 -0.50 1.57 1.12 7 225.00 0.75 298.00 224.99 108.99 232832.05 2485779.13 1.25 -0.78 0.47 1.44 8 250.00 1.17 306.00 249.99 133.99 232831.70 2485779.37 1.48 -1.13 1.76 1.85 9 275.00 1.25 302.00 274.98 158.98 1 232831.27 2485779.67 1.78 -1.57 0.47 2.37 10 300.00 1.17 304.00, 299.98 183.98 232830.84 2485779.97 2.06 -2.01 0.36 2.88 Tie -In 313.00 1.50 292.00 312.98 196.98 232830.57 2485780.11 2.20 -2.28 3.31 -1.45 1 395.00 3.00 205.00 394.93 278.93 232828.64 2485778.62 0.66 -4.18 4.00 0.57 2 490.00 5.25 198.00 489.68 373.68 232826.10 2485772.28 -5.73 -6.58 2.42 7.38 3 550.00 6.25 188.00 549.37 433.37, 232824.66 2485766.47 -11.58 -7.88 2.35 13.35 4 650.00 ] 8.75 179.00 648.51 532.51 1 232823.74 2485753.49 -24.57 -8.50 2.75 25.98 5 710.00 10.00 176.00: 707.71 591.71 232823.96 2485743.72 -34.33 -8.06 2.24 35.20 6 809.00 11.00 174.00 805.05 689.05 232825.14 2485725.72 -52.30 -6.47 1.07 51.95 7 870.00 13.00 174.00 864.72 748.72 232826.18 2485713.08 -64.91 -5.15 3.28 63.65 8 949.00 16.00 i- 175.00 941.19 825.19 232827.61 ' 2485693.36 -84.60 i -3.27 3.81 81.97 9 1047.00 19.50 173.00 1034.51 918.51 i 232830.10 2485663.60 - 114.30 -0.10 3.62 109.50 10 1138.00 22.50 174.00 1119.46 1003.46 232833.04 2485631.12 - 146.70 3.57 3.32 139.47 11 1234.00 ] 26.00 176.00 , 1206.98 1090.98 232835.53 2485591.78 - 185.97 6.96 3.74 176.11 12 1364.00 30.00 176.00 1321.74 � 1205.74 232838.40 2485530.83 - 246.84 11.22 3.08 1 233.18 13 1495.00 31.25 176.00 1434.46 1318.46 232841.54 2485464.18 - 313.41 15.87 0.95 295.59 14 1590.00 32.00 177.00 1515.36 1399.36 232843.45 2485414.40 - 363.13 18.91 0.96 342.34 15 1780.00 36.00 180.00 1672.85 1556.85 232843.67 2485308.21 - 469.29 21.55 2.28 443.25 16 1890.00 33.75 180.00 1763.09 1647.09 232842.24 2485245.33 - 532.19 21.55 2.05 503.49 17 1959.00 1 34.00 179.00 1820.38 1704.38 232841.70 2485206.88 - 570.64 21.88 0.89 540.22 18 2056.00 34.50 178.00 1900.56 i 1784.56 232841.89 2485152.29 - 625.22 23.32 0.78 592.07 19 2241.00 33.75 177.00 2053.70 1937.70 232844.05 2485048.53 - 728.90 27.83 0.51 690.07 20 2367.00 36.00 178.00 2157.07 2041.07 232845.53 2484976.51 - 800.87 30.96 1.84 758.10 21 2554.00 35.00 178.00 2309.31 2193.31 232846.85 2484867.93 - 909.39 34.75 0.53 860.95 22 2712.00 34.25 175.00 2439.33 2323.33 232850.27 2484778.25 - 998.98 40.21 1.18 945.18 23 2806.00 35.00 174.00 2516.68 ] 2400.68 232854.18 2484724.98 - 1052.14 45.33 1.00 _ 994.62 24 2906.00 35.00 176.00 2598.60 2482.60 232857.88 2484667.75 - 1109.27 50.33 1.15 1047.90 25 2968.00 36.00 177.00 2649.08 2533.08 232859.26 2484631.78 - 1145.21 52.52 1.87 1081.68 26 3008.00 37.50 175.00 2681.13 2565.13 232860.39 2484607.87 - 1169.08 54.20 4.80 1104.06 27 3106.00 37.75 179.00 2758.76 2642.76 232862.16 2484548.10 - 1228.80 57.32 2.50 1160.36 28 3168.00 37.00 179.00 2808.03 2692.03 232861.96 2484510.47 - 1266.43 57.98 1.21 1196.21 29 3228.00 35.75 183.00 2856.34 2740.34 232860.55 2484474.93 - 1301.99 57.38 4.47 1230.44 30 3259.00 36.00 185.00 2881.46 2765.46 232858.87 2484456.84 - 1320.11 56.11 3.87 1248.16 31 3398.00, 37.00 181.00 2993.21 2877.21 232852.70 2484374.43 - 1402.64 51.82 1.86 1328.43 32 3563.00 37.75 182.00 3124.33 3008.33 232847.79 2484274.40 - 1502.76 49.19 0.58 1425.08 33 3722.00 38.50 182.00 3249.41 3133.41 232842.14 2484176.40 - 1600.86 45.76 0.47 1520.02 34 3910.00 40.00 181.00 3395.00 3279.00 232836.34; 2484057.60 - 1719.77. 42.66 0.87 1634.78 35 4065.00 38.00 182.00 3515.45 3399.45 232831.58 2483960.18 - 1817.27 40.13 1.35 1728.89 36 4224.00 37.75 185.00 3640.97 3524.97 232823.42 2483862.94 - 1914.68 34.18 1.17 1823.90 37 4371.00 38.00 183.00 3757.01 3641.01 232815.08 2483773.09 - 2004.70 27.89 0.85 1911.92 38 4539.00 38.00 184.00 3889.39 3773.39 232806.42 2483670.02 - 2107.93 21.57 0.37 2012.61 39 4693.00 37.75 183.00 4010.95 3894.95 232798.50 2483575.81 - 2202.30 15.80 0.43 2104.65 40 5007.00 37.00 185.00 4260.49 4144.49 232780.92 2483386.05 - 2392.42 2.53 0.45 2290.55 41 5162.00 37.00 184.00 4384.28 4268.28 232771.48 2483293.25 - 2485.41 -4.78 0.39 1 2381.71 42 5320.00 36.25 187.00 4511.09 4395.09 232760.34 2483199.68 - 2579.22 -13.79 1.23 2474.14 43 5472.00 36.501 188.00 4633.48 4517.48 232746.54 2483110.60 - 2668.59 -25.56 0.42 2563.12 44 5595.00 33.00 194.00 4734.56 4618.56] 232731.78 2483042.15 - 2737.36 -38.77 3.98 2632.78 1 :, • • Measured Angle Azimuth TVD -RKB ND j X Y N / -S E / -W DLS Vert. Sec SVY# Depth deg deg ft Subsea ft ft ft ft deg /100 ft ft 45 5620.00 33.50 196.001 4755.46 4639.46 232727.93 2483028.99 - 2750.59 -42.31 4.82 2646.48 46 5782.00 34.00 203.00 4890.21 4774.21 232695.98 2482945.00 - 2835.30, -72.35 2.42, 2736.24 47 5833.00 33.25 205.00 4932.68 4816.68 232683.92 2482919.47 - 2861.09 -83.83 2.621 2764.25 48 6009.00 33.25 , 205.00 5079.87 4963.87 232641.16.2482832.96 - 2948.55 -124.61 0.00 2859.74 49 6163.00 33.75' 204.00 5208.29 - 3025.90 - 159.85 0.48 2943.96 50 6261.00 33.25 205.00 5290.01 5174.01 75 - 3075.12 - 182.28 0.76 2997.55 51 6417.00. 34.00 204.00 5419.90 5303.901 232543.03 2482629.97 - 3153.72 - 218.10 0.60 3083.13 52 6667.00 34.00 207.001 5627.18 5511.18 232480.01 2482505.23 - 3279.87 - 278.26 0.67 3221.26 53 6979.00 35.00 _ 210.00 5884.32 5768.32 232392.15 2482351.96 - 3435.10 - 362.61 0.63 3394.19 54 7255.00 41.00 209.00 6101.72 5985.72 232305.26 2482206.03 - 3582.97 - 446.16 2.19 3559.85 55 7354.00 41.00 209.00 6176.43 6060.43 232272.4912482149.96 - 3639.78 - 477.65 0.00 3623.31 56 7530.00 41.50 208.00 6308.76 6192.76 232214.82 2482049.27 - 3741.76 - 533.01 0.47 3736.91 57 7739.00 39.00 209.00 6468.26 6352.26; 232147.74 2481932.09 - 3860.44 - 597.42 1.24 3869.10 58 8073.001 37.25 208.00 6731.00 6615.00 232045.23 2481753.19 - 4041.62 - 695.83 0.56 4070.94 59 8214.00 38.75 207.00i 6842.11 6726.11 232003.42 2481677.12 - 4118.63 - 735.90 1.15 4156.21 60 8310.00 37.75 210.00 6917.50 6801.50 231973.90 2481625.55 - 4170.85 - 764.24 2.20 4214.38 61 8467.00 36.00 210.00 7043.09 6927.09 231924.95 2481545.06 - 4252.44 - 811.34 1.11 4306.07 62 8561.00 35.25 211.00 7119.50 7003.50 231896.10 2481498.53 - 4299.61 - 839.13 1.01 4359.25 63 8591.00 35.75 211.00 7143.92 7027.92 231886.79 2481483.81 - 4314.55 - 848.10 1.67 4376.13 64 8681.00 37.00 210.00 7216.38 7100.38 231858.67 2481438.44 - 4360.54 - 875.18 1.54 4427.97 65 8716.00 37.00 214.00, 7244.34 7128.34 231847.11 2481420.85 - 4378.39 - 886.34 6.88 4448.28 66 8770.00 36.50 214.00 7287.611 231828.44 2481394.48 - 4405.18 - 904.41 0.93 4479.13 67 9003.00 35.75 218.00 7475.841 7359.84 231745.27 2481285.24 - 4516.28 - 985.08 1.06 4608.74 68 9128.00 34.50 218.00 7578.07 7462.07 231699.71 2481229.59 - 4572.95 - 1029.35 1.00 4675.76 69 9309.00 33.50 219.00 7728.13 7612.13 231634.93 2481151.83 - 4652.17 - 1092.35 0.63 4769.75 70 9434.00 32.50 221.00 7832.96 7716.96 231590.02 2481100.69 -4704.32 - 1136.09 1.18 4832.28 71 9604.00 31.00 225.00 7977.53 7861.53 231527.62 2481036.66 - 4769.76 - 1197.02 1.52 4912.48 72 9771.00 30.00 226.00 8121.421 8005.42 231465.84 2480978.63 - 4829.17 - 1257.46 0.67 4986.77 73 9886.00 29.751 226.00 8221.14 8105.14 231423.74 2480939.79 - 4868.97 - 1298.67 0.22 5036.74 74 9997.00 29.25 226.00 8317.75 8201.75 231383.57 2480902.73 - 4906.93 - 1337.99 0.45 5084.41 75 10094.00 28.25 226.00 8402.79 8286.79 231349.28 2480871.09 - 4939.34 - 1371.55 1.03 5125.11 76 10205.00 27.75 227.00, 8500.80 8384.80 231310.68 2480836.091 - 4975.22 - 1409.35 0.62 5170.34 77 10305.00 26.75 228.00 8589.70 8473.70 231276.23 2480805.93 - 5006.15 - 1443.10 1.10 5209.68 78 10444.00 24.25 230.00 8715.15 8599.15 231230.23 2480767.68 - 5045.44 - 1488.22 1.90 5260.28 79 10533.00 25.001 232.00 8796.06 8680.06 231200.88 2480745.01 - 5068.77 - 1517.04 1.26 5290.92 80 10555.00 25.00 232.00 8816.00 8700.001231193.43 2480739.45 - 5074.49 - 1524.37 0.00 5298.51 2 if • ACB RRP ENERGY AFE Approved XTO ENERGY MGS A33 -14 WIW EAST FLANK, COOK INLET, ALASKA ELIMINATE TUBING /CASING PRESSURE COMMUNICATION AFE #: 1202973 SURFACE CASING: 10 -3/4 ", 40.5 #, J -55 @ 1,890'. Cmt w /1,500 sx & top out w/475 sx. PRODUCTION CASING: 7 ", 23.0 #, N -80, BTC fr /surface — 6,435' 7 ", 26.0 #, N -80, BTC fr/6,435' — 9,831' 7 ", 29.0 #, N -80, BTC fr/9,831' — 10,531' Cmtw /1,100 sx PRODUCTION LINER: 5 ", 18.0 #, N -80 SFJP fr/8,956' — 10,432'. Cmt w /150 sx. 5 ", 18.0 #, N -80, Hydril 513 fr /surface — 8,956'. Cmt w /150 sx. PBTD: 10,432' TUBING & PACKER: 2 -3/8 ", 4.7 #, N -80, 8rd, EUE, ABMOD tbg Baker DB permanent packer Size 32 -26 Packer set @ 9,610' & EOT @ 9,649' (See attached WBD for completion details) PERFORATIONS: HC -HD: 9,715' — 9,804' HK -HN: 10,060' — 10,162' HN -HR (U): 10,162' — 10,239' HN -HR (L): 10,260' — 10,302' HR -HZ: 10,328' — 10,419' BHST: 170° F BHP: +1- 6,000 psi / DEVIATION: Maximum inclination: 41.5° @ 7,530' MD (6,309' TVD) Maximum DLS: 6.88° /100' @ 8,716' MD (7,244' TVD) Complete deviation survey is attached SMALLEST ID: 2 -3/8" XN- nipple @ 9,641' (1.791" ID) CURRENT STATUS: 500 BWIPD @ 3,500 psig TP & 3,500 psig CP OBJECTIVE: Eliminate tubing- pressure communication by replacing tubing string and packer A33 -14 WIW Eliminate TCA Press Comm Procedure_1- 9- 2012.docx ACB 1 of 4 • S MATERIALS REQUIRED: 60 bbls Safe -Vis for kill pill & gel sweeps (MI SWACO) 2,500 sx CaBr2 powder for workover fluid (MI SWACO) 40 gal EC 1447 corrosion inhibitor for packer fluid (NALCO) 1,000 gal 10% pickle acid (BJ) 1,000 lbs soda ash (MI SWACO) PTS Tank for pickle acid returns NOTES: Anticipated BHP is +/- 6,000 psi Workover fluid will be 14.8 ppg CaBr fluid (360 lbs CaBr / 0.7487 bbls FW Safe -Vis kill pill fluid mix recipe is (314 lbs CaBr2 + 70 lbs Safe -Carb 20 + 15 lbs Safe -Carb 40 + 3 lbs Safe -Vis OGS) / 0.7835 bbl FW Safe -Vis gel sweep recipe is (3 lbs Safe -Vis OGS) / 1 bbl 14.8 ppg CaBr fluid Barney to make SL run w /1.75" GR to XN- nipple @ 9,641' prior to MIRU WORKOVER PROCEDURE 1. SI well 2 weeks prior to RU. Bleed off pressure to header. 2. MIRU derrick. 3. Mix 380 bbls — 14.8 ppg CaBr2 fluid for workover fluid. Mix 20 bbls Safe -Vis kill pill. Bullhead 20 bbls Safe -Vis kill pill down tubing and displace with 37 bbls 14.8 ppg CaBr2 fluid. Open TCA. Continue pumping CaBr fluid down tubing and circulate wellbore fluids out TCA. Send wellbore fluids to disposal well MGS A44 -11 SWD. Recover the CaBr2 fluid and maintain 14.8 ppg. Ensure returns are 14.8 ppg CaBr fluid. Stop pumping. Verify that the well is dead. 4. MI 11,000' — 2 -7/8 ", 10.4 #, SLH90 HT drill pipe (1.975" ID) and 9 — 3 -1/8" drill collars (1.5" ID). O c.Ltp ;ez abut ri i n s�,k'i 5. Notify the AOGCC 48 hours prior to the BOP test. est. Set BPVs. ND WH. Install riser. NU BOPE. Remove BPVs. Set double check valves. Ensure BOPE has VPRs for 2 -3/8" to 2 -7/8" pie installed. Send WH to Cameron. New WH will have stainless steel valves. 3600 ,,s:- 6 6 1 ' 7 2 V co P � �.1d. 6. Have Pollard WL on standby to cut tubing before proceeding. RU slips and tongs for 2 -3/8" tubing. PU on tubing to release seal assembly. If seal assembly releases, skip Step 7 and proceed with Step 8. If seal assembly does not release, proceed to Step 7 to cut tubing. RU Pollard WL. RIH with tubing punch and CCL. Punch hole in tubing at 9,592.5' MD (middle of the first full joint above the packer). POH. RIH with 1- 11/16" radial torch and CCL. Cut tubing at 9,593' MD, just below the hole. POH and RD WL. 8. Circulate bottoms up with 14.8 ppg CaBr fluid. TOH and LD 2 -3/8" tubing. Check tubing for NORM while TOH. Complete NORM Screening Certificate and send to Ryan Tunseth. Send tubing to onshore and sell it for scrap. Send tubing hanger to Cameron. New tubing hanger will be stainless steel. 9. RU Iron Roughneck. (Only proceed with the remainder of this step if the tubing was cut; otherwise, proceed to Step 10.) PU OS BHA on 3 -1/8" DCs and 2 -7/8" DP. TIH to tubing stub at 9,593'. Work OS over tubing stub. Release seal assembly and POH with tubing stub and seal assembly. LD OS BHA. A33 -14 WIW Eliminate TCA Press Comm Procedure_1- 9- 2012.docx ACB 2 of 4 • • 10. PU 5" packer milling assembly on 3 -1/8" DCs and 2 -7/8" DP. TIH to top of packer at 9,610'. Establish string weight. Mill on packer per TIW's packer milling instructions. When the packer drops, circulate bottoms up with a 20 bbl Safe -Vis gel sweep followed by 14.8 ppg CaBr fluid. POH with the packer and tailpipe. If the packer does not come out, TIH with spear and grapple to retrieve packer. Push packer to PBTD at 10,432'. POH slowly with packer and tailpipe assembly. 11. TIH with 4 -1/8" bit, 750' - 2 -7/8" DP, 5" casing scraper, and 2 -7/8" DP. Clean out to PBTD at 10,432'. Keep casing scraper above top perf at 9,715'. Pump a 20 bbl Safe -Vis gel sweep followed by 14.8 ppg CaBr Spot a 20 bbl Safe -Vis pill on bottom to cover perfs. TOH and LD DP and BHA. 12. MI 10,000' - 2 -7/8 ", 6.5 #, 1% Cr, 8rd, EUE tubing (tubing footage includes 4% excess). 13. RU slips and tongs for 2 -7/8" tubing. TIH with new 5" TIW HB -BP chrome permanent packer on 2 -7/8 ", 6.5 #, 1% Cr, 8rd, EUE tubing. Run sliding sleeve in closed position. Completion details in table below: Item Length (ft) Top (ft MD) Bottom (ft MD) 2 -7/8" 6.5# 1% Cr 8rd EUE tbg 300 0 300 4' Pup Jt, 2 -7/8" 6.5# 1% Cr 8rd EUE 4 300 304 2 -7/8" X Nipple (2.313" ID) 8rd 9Cr 1 304 305 6' Pup Jt, 2 -7/8" 6.5# 1% Cr 8rd EUE 4 305 309 2 -7/8" 6.5# 1% Cr 8rd EUE tbg 9,236 309 9,545 4' Pup Jt, 2 -7/8" 6.5# 1% Cr 8rd EUE 4 9,545 9,549 2 -7/8" Hall. XU SS w/X Nipple (2.313" ID) 8rd (9 Cr) 4 9,549 9,553 6' Pup Jt, 2 -7/8" 6.5# 1% Cr 8rd EUE 6 9,553 9,559 Anchor w /Seals 8rd EUE (13 Cr) 1 9,559 9,560 TIW 5" HB -BP Permanent Packer (13 Cr) 4 9,560 9,564 Rw - 10' Millout Extension (13 Cr) 10 9,564 9,574 XO MOE x 2 -7/8" 8rd (13 Cr) 1 9,574 9,575 6' Pup Jt, 2 -7/8" 6.5# 1% Cr 8rd EUE 6 9,575 9,581 2 -7/8" XN Nipple (2.205" ID) 8rd (9 Cr) 1 9,581 9,582 4' Pup Jt, 2 -7/8" 6.5# 1% Cr 8rd EUE 4 9,582 9,586 WL REG (13 Cr) 1 9,586 9,587 14. PU landing joint. Space out tubing. MU and land new stainless steel tubing hanger. 15. RU BJ to the tubing_ to pump 1,000 gal 10% pickle acid. RU PTS tank. Put 1,000 lbs soda ash in PTS tank to neutralize acid returns. Pressure test lines to 2,000 psig. Establish circulation down the tubing with CaBr fluid. Pump 500 gal 10% pickle acid down tubing at 2 - 3 BPM and displace with CaBr fluid. Under - displace acid 500' from EOT. RU rig pump to TCA. Reverse circulate the acid to the PTS tank. Repeat with the remaining 500 gal pickle acid. Pump spent acid down disposal well MGSA44 -1L SWD. RD BJ. 16. RU SL. Pressure test lubricator to 4,000 psig. RIH with PXN plug and set it in XN- nipple at 9,581'. RD SL. Pressure test tubing to 1,000 psig for 15 minutes. Continue to pressure up to 3,500 psig to set the packer per TIW' s packer setting instructions. Once the packer is set, pressure up to 4,000 psig and hold for 15 minutes to pressure test the tubing. Bleed off pressure. A33 -14 WIW_Eliminate TCA Press Comm Procedure_I- 9- 2012.docx ACB 3 of 4 • S x" ik 17. Perform MIT on the 2 -7/8" x 5" TCA. Record MIT on chart. With the packer set at 9,560' MD (7,940' TVD), pressure test the TCA to 2,000 psig (7,940' x 0.25 psi /ft = 2,000 psi). Hold pressure for 30 minutes. Bleed off pressure. t k 36 18. Set BPV. ND BOPE and riser. NU new stainless steel WH. Pull BPV. Set two -way check and test WH to 5,000 psig. Remove 2 -way check. WH must contain a SSV. )(/ 19. RU SL. Pressure test lubricator to 4,000 psig. RIH and open sliding sleeve at 9,543'. POH. RU rig pump to tubing and pump 8.4 ppg FIW down tubing and circulate CaBr2 fluid out TCA. Recover and store CaBr2 fluid. Continue pumping until returns are 8.4 ppg FIW. RD rig pump from tubing. 20. RU rig pump to TCA. Reverse circulate 125 bbls FIW mixed with 40 gal Nalco EC- 1447W1Uorrnsion inhibitor for packer fluid. Volume contains 30 bbls excess. RD rig pump. 21. RIH with SL and close sliding sleeve at 9,543'. RIH to retrieve PXN plug. Pressure test tubing to 4,000 psig to verify that sliding sleeve is closed. Bleed off pressure to 1,500 psig. Retrieve P_XJ Lplug. POH with plug. RD SL. RD and release rig. 22. Flow back well to PTS tank to recover CaBr2 fluid. Flow back until returns are consistent with injected FIW. Send returns to disposal well. 23. PWOI. 5 - E"�� ( �•�e_j e 4 .1. . IN; he s Y �1 , a Alec Bridge g Operations Engineer A33 -14 WIW Eliminate TCA Press Comm Procedure_1- 9- 2012.docx ACB 4 of 4 • • ACB 11/30/2012 ;(1.0 NERGY MGS A33 -14 WIW Cook Inlet, Alaska CURRENT COMPLETION Leg 4, Conductor 30 07/22/200. ALL TBG: 4.7 #, N -80, 8rd, EUE, ABMOD / API No.: 50- 733 -20057 % Item Length, ft Top Bottom / , Spud: 11/02/1967 ! KB 35 0 35 • • • Cameron tbg hanger 1 35 36 Surf Csg: * 2-3/8" x 2' pup jt 2 36 38 10 -3/4 ", 40.5 #, J55 @ 1,890'. / s jts 2-3 /8" tbg 291 38 329 Cmt w/1,500 sx cmt. Top out w /475 sx cmt. f A Xnipple (1.875" ID) 1 329 330 286 jts 2 -3/8" tbg 9,246 330 9,576 Orl Inal Prod Cs Xnipple (1.875" ID) 1 9,576 9,577 g g' 1 jt 2 -3/8" tbg 32 9,577 9,609 7 ", 23 #, N80 BTC: 0 - 6,435' XO 2 -7/8" EUE in x 2 -3/8" EUE box 1 9,609 9,610 7 ", 26 #, N80 BTC: 6,435' - 9,831' Baker DB perm packer Size 32 -26 3 9,610 9,613 7 ", 29 #, N80 BTC: 9,831' - 10,531' Seal Bore Extension 15 9,613 6,628 Cmt w/1,100 sx cmt. 2 -3/8" x 4' pup jt 4 9,628 6,632 Xnipple (1.875" ID) 1 9,632 9,633 7/14/00: 2 -3/8" x 8' pup jt 8 9,633 9,641 Cut 7" csg @ 88'. Ran OS & 7 ", 46.2# csg XN nipple (1.791° ID) 1 9,641 9,642 ee & install new WH and SS tree. 2-3/8" x 6' pup jt 6 9,642 9,648 WL REG 1 9,648 9,649 ► *mow; ► A j; :•:.' 05/21/84: • ;: : �i ►i�i�D = i, 4 7" Csg leak @ 6,150'. Sqz'd w /200 sx CI G cmt. i ii::'. -* " ... :.:. , ::: .. ::::, ... .::: r �' :::. Note on perfs: all original perfs sgz'd & covered w /5" liner. Re -perfd all intervals 5/28/84: :: except G members, HE -HF & HI -HK. Ran 5 ", 18 #, N80 SFJP liner fr /8,956' - 10,432'. %%% Cmt w /150 sx CI G cmt. GN -GO: 9,061' 9,083' (Behind 5" Liner) ��♦ .. GR -GS: 9,435' - 9,451' (Behind 5" Liner) 7/16/00: 6. •' ** Q - GR -GS: 9,456' - 9,472' (Behind 5" Liner) Ran 5 ", 18 #, N80, Hydril 513 tie -back liner fr/ � � � � � 8,956' surf. / "� ► � � Cmt w /132 bbl CI G cmt. Circ cmt to surf. / /�i ��� HC -HD: 9,715' - 9,804' (Behind 5" Liner) ■ HC -HD: 9,715' - 9,804' i. • ` ! O i r'� / w ►� +/% HE -HF: 9,860' - 9,888' (Behind 5" Liner) *' r HI -HK: 9,954' - 9,995' (Behind 5 Liner) __ HK -HN: 10,008' - 10,162' (Behind 5" Liner) � HK -HN: 10,060' - 10,162' ■ � , HN -HR: 10,173' - 10,239' (Behind 5" Liner) � � HN -HR: 10,162' - 10,239' ► HN -HR: 10,261' - 10,302' (Behind 5" Liner) ` ►�� . %% HN -HR: 10,260' - 10,302' ■ . ► +a HR HZ: 10,328' 10,460' (Behind 5" Liner) r" HR -HZ: 10,328' - 10,419' PBTD. 10,432' i t . 05/21/84: TD: 10,555' �/ All perfs sgz'd w/250 sx cmt below CICR @ 9,593'. 1 • • • f r'o ACB 01/08/2013 ENERGY MGS A33 -14 WIW Cook Inlet, Alaska PROPOSED COMPLETION Leg 4, Conductor 30 - ALL TBG & PUP JTS TO BE 2 -7/8 ", 6.5 #, 1% Cr, 8rd, EUE API No.: 50- 733 -20057 / : i i / / Item Length (ft) Top (it MD) Bottom (ft MD) Spud: 11/02/1967 2-7/8" 8.5# 1% Cr 8rd EUE tbg 300 0 300 4' Pup Jt, 2 -7/8" 6.5# 1% Cr 8rd EUE 4 300 304 / :.:' •:. � 2 -7/8" X Nipple (2.313" ID) 8rd 9Cr 1 304 305 Surf Csg: / // / / � /// 6' Pup Jt, 2 -7/8" 6.5# 1% Cr 8rd EUE 4 305 309 # 5 1 890'. '?• I 2 7/8" 6.5# 1% Cr 8rd EUE tbg 9,236 309 9,545 10-3/4", 40.5 , J5 @ , I 4 Pup Jt, 2-7/8" 6.5# 1% Cr 8rd EUE 4 9,545 9,549 Cmt w/1 500 sx cmt. Top out w1475 sx cmt. 2 -7/8" Hall. XU SS w/X Nipple (2.313 ID) 8rd (9 Cr) 1 9,549 9,550 p 6' Pup Jt, 2 -7/8" 6.5# 1% Cr 8rd EUE 6 9,550 9,556 ee Anchor w /Seals 8rd EUE (13 Cr) 4 9,556 9,580 Original Prod Csg: ::: ':.*: •:. T1W 5" HB -BP Permanent Packer (13 Cr) 4 9,560 9,564 7 ", 23 #, N80 BTC: 0 - 6,435' .:: 10' Millout Extension (13 Cr) 10 9,564 9,574 XO MOE x 2 -7/8" 8rd (13 Cr) 1 9,574 9,575 7 ", 26 #, N80 BTC: 6,435' - 9,831' 6' Pup Jt, 2 -7/8" 6.5# 1% Cr 8rd EUE 6 9,575 9,581 7", 29 #, N80 BTC: 9,831' - 10,531' 2 -7/8" XN Nipple (2.205" ID) 8rd (9 Cr) 1 9,581 9,582 Cmt w/1,100 sx cmt. .:. :.: 4' Pup Jt, 2 -7/8" 6.5# 1% Cr 8rd EUE 4 9,582 9,586 WL REG (13 Cr) 1 9,586 9,587 7/14/00: Cut 7" csg @ 88'. Ran OS & 7 ", 46.2# csg & install new WH and SS tree. ,41 ":* 05/21/84: o. 4 ::: :.: 7" Csg leak @ 6,150'. Sqz'd w /200 sx CI G cmt. I: il : ( Note on perfs: all original perfs sqz'd & • covered w /5" liner. Re-perfd all intervals 5/28/84: except G members, HE -HF & HI -HK. Ran 5 ", 18 #, N80 SFJP liner fr/8,956' - 10,432'. '_'� Cmt w /150 sx CI G cmt. �.• GN GO: 9061' 9083' / , , (Behind 5" Liner) ;:: �� .. � GR -GS: 9,435' - 9,451' (Behind 5" Liner) 7 7/16/00: � - -. Ran 5 ", 18 #, N80, Hydril 513 tie -back liner fr/ � , � GR-GS: 9,456' - 9,472' (Behind 5" Liner) 8,956' - surf. � 1 • HC -HD: 9,715' - 9,804' (Behind 5" Liner) Cmt w/132 bbl CI G cmt. Circ cmt to surf. HC -HD: 9,715' - 9,804' ■ � / j 4 HE -HF: 9,860' - 9,888' (Behind 5" Liner) . HI HK: 9,954' - 9,995' (Behind 5" Liner) � ...4 A HK -HN: 10,008' - 10,162' (Behind 5" Liner) ■ r IP HK -HN: 10,060' - 10,162' � ��� HN -HR: 10,173' - 10,239' (Behind 5" Liner) � i# HN -HR: 10,162' - 10,239' , t•= HN -HR: 10,261' - 10,302' (Behind 5" Liner) �% HN-HR: 10,260' 10,302' � , HR -HZ: 10,328' - 10,460' (Behind 5" Liner) % - I. HR -HZ: 10,328' - 10,419' • PBTD: 10,432' , 05/21/84: TD: 10,555' or � � All perfs sqz'd w/250 sx cmt below CICR @ 9,593'. ,„ • • • e k CAMERON XTO PLATFORM A Well 33 -14 Equipment Replacement WH for 2 -7/8" tbg Tree �:� 2 -9/16 API 5K Run with 2 -1/16 API 5K Wing ,=, . Valves in run of tree use R -27 Ring Gaskets Valve on wing use R -24 Ring Gaskets Tubing Hanger has 2 -1/2" Type H BPV Profile o 0 �� / 0 0` 1)� 00 _ �.�I 1.1 R -27 s N O ,� ce `00 0 //00 R -27 % % 0 nu 1.1 00 `0 oj".o 000. Tubing Head Adapter 7 -1/16 API 5K x 2 -9/16 API 5K rr' EM � 18 Replacement Tubing Hanger 11" Bowl, PN 154635- 01 -05 -02 • 2 -7/8 EUE 8rd Box Top & Bottom. R -46 Ring Gasket Bottom w/2 -1/2 Type "H" BPV w/ two 1/4" � III*: R -27 Ring Gasket Top +:11 R46 NPT Continuous Control Line preps �og Ii 1 �� c PN 2120026 -08 -02 Tubing Spool • 11 "API 5K x 7- 1/16" API 5K A �IIIIII - _ - - ) PN 2161081 -01 -01 I (ok 1111. R -54 Ring Gasket Bottom _ o 0 R-46 Ring Gasket Top Annulus Outlets are 2 -1/16 API ism am ° R -24 Ring Gasket ` " :_i' 10 x 5 CA -22 Slips R -54 m PN 8811144 with Primary Seal Casing Spool %1% Vf i %n � � and NX Bushing 11 "API 5K x 11" API 5K II - = J � PN 156784- 01 -01 -01 M��� II�� 111 0 o li.� '--,' R -54 Ring Gasket Bottom R -54 Ring Gasket Top - Annulus Outlets are 2 -1/16 API on ism cs t !� 10x7CASli s "" R -24 Ring Gasket ^ - PN 017890- 01with Primary Seal =-4.11 R -54 .I. dim and 7" X Bushing Lowermost Casing Head 1 .. ii e.1 11" 3K ( #9 Clamp) Hub x 11 API 5K Flange Top PN 650544 -01 % " ! e E I � R -53 MODIFIED Ring Gasket Bottom I Mil l 1o IIII■I_14 R -54 Ring Gasket Top o o - Annulus Outlets are 2 -1/16 API 5K °� R -24 Ring Gasket . o • ,� )- l 1 ,J 2 -1/16 API 5K R -24 Ring Gasket 011.1111 O 5/23/2012 • S 13.625 BOP Schematic.xls XTO - ENERGY 'KB Elevation n Date: 5/23/2012 "Rig Floor" Flow Flow line Nipple Hydril r 13 5/8" 5m 13 5/8" 5m Annular double ram ` / preventer WE IIT1 MI all MITI I. _ ( ) ■ l! Vi( it '411— 7 • = 13 518" 5m Cameron � — ' 0 I I k I �� I Pipe rams I i 3 y rIMINIM k •_ M n '' J ` 13 5/8" 5m Cameron 1 i I —S Blind Rams Illemesess _._ U C11;1° C3---i. F F LU all ulw J.L Ilia ': II� � : • II�III___ , 2 1/16" Kill Line 7n.11m 3 1/8 "Choke Line • I I 2 1/16" 3 1/ 8 3 1/8" 5m 5m 5m Hydraulic Manual Manual Valve Valves valve / 13 5/8 5m \ / riser 135/8 "5m I uuwwiulw � Mud Cross with 3 1/8" outlets Page 1 • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Friday, December 28, 2012 TO: Supervisor Regg �( ( / I -, l ( 11 r l 3 SUBJECT: Mechanical Integrity Tests P.I. P I XTO ENERGY INC A33 -14 FROM: Lou Grimaldi MGS A33 -14 Petroleum Inspector Src: Inspector Reviewed By: P.I. SuprvJ6:e- NON- CONFIDENTIAL Comm Well Name MGS A33 -14 API Well Number 50- 733 - 20057 -00 -00 Inspector Name: Lou Grimaldi Permit Number: 167 -068 -0 Inspection Date: 12/23/2012 insp Num: mitLGI21227093401 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min Well YP ln' J W 1 TVD 7983 IA ? 3500 - 3200 3150 3150 ' �– —� 4 T e i PTD 1670680 ' Type Test sPT (Test p j 500 OA 10 545 525 525 - I — — — _L — - Interval IREQVAR 1P /F 1 P I Tubing I 3550 �'I 3350 3300 3300 - Notes: Outer Annulus pressure test as required by AI0 9.008. Well was shut -in during MIT explaining drop in Tub /IA pressure, necessary due to HP pilot configuration. OA held pressure test correctly. SCANNED APR 1 1 2013 Friday, December 28, 2012 Page 1 of 1 A33-14 (1670680) Rate and Pressure Monitoring Injected [bbl] 10-3/4" Surf [psig] 7" Intermed [psig] TBG Annulus [psig] WH Injection [psig] Comments Hrs Down 11/1/2012 523 10 8 3,500 3,550 1 11/2/2012 0 10 8 2,850 2,900 24 11/3/2012 0 10 8 2,725 2,750 24 11/4/2012 0 10 8 2,650 2,700 24 11/5/2012 0 10 8 2,625 2,650 24 11/6/2012 0 10 8 2,600 2,650 24 11/7/2012 0 10 8 2,575 2,600 24 11/8/2012 0 12 10 2,575 2,600 24 11/9/2012 0 12 10 2,550 2,600 24 11/10/2012 0 12 10 2,550 2,600 24 11/11/2012 0 12 10 2,550 2,600 24 11/12/2012 40 12 10 3,100 3,150 21 11/13/2012 750 12 10 3,350 3,400 0 11/14/2012 623 12 8 3,450 3,550 5 11/15/2012 0 12 9 2,625 2,675 24 11/16/2012 0 12 9 2,625 2,675 24 11/17/2012 0 12 9 2,550 2,600 24 11/18/2012 0 12 9 2,550 2,600 24 11/19/2012 0 12 9 2,500 2,550 24 11/20/2012 0 12 9 2,500 2,550 24 11/21/2012 0 12 6 2,500 2,550 24 11/22/2012 0 10 6 2,450 2,500 24 11/23/2012 0 10 6 2,450 2,500 24 11/24/2012 0 10 6 2,450 2,500 24 11/25/2012 433 5 3 3,075 3,075 0 11/26/2012 803 8 4 3,450 3,550 0 11/27/2012 728 5 2 3,475 3,550 0 11/28/2012 708 5 2 3,475 3,550 0 11/29/2012 667 5 2 3,475 3,550 0 11/30/2012 630 5 2 3,475 3,550 0 XTO Energy - A33-14 (1670680) Rate and Pressure Monitoring Administrative Approval AIO No. 9.008 5,000 —� TBG Annulus [psig] 1000 - WH Injection [psig] 4,500 Injection Rate [bbl/d] 900 —f—Surface Casing [psig] 4,000-9 7" Intermed [psig] 800 @ z 3,500 700 ,Z$ OP a 3,000 600 m is =o v 500 2,500 v C 400 0 2,000 U M t 3 1,500 300 200 1,000 100 500 0 - - - - T - 0 ^ti�ti ti 11, ,yo ,yo ,yo ,yo ,yo ,yo ,yo ,yo,yo do ,yo ,yo ,yo ,yo ,yo ,yo • •� q Regg, James B (DOA) 16706e0 From: Paul_Figel @xtoenergy.com ) Sent: Monday, August 06, 2012 6:14 AM - Re fl 7 /� z.-- To: Regg, James B (DOA); Scott_Griffith @xtoenergy.com; Barney_Phillips @xtoenergy.com; Greg_Duggin @xtoenergy.com; Schwartz, Guy L (DOA) Subject: XTO Energy - A33 -14 (1670680) Rate and Pressure Monitoring July 2012 AIO # 9 -008 Attachments: A33 -14 Rate and Pressure Monitoring July 2012 (AIO 9.008).xlsx Attached is the July 2012 injection rate and wellhead pressure monitoring reports for the Middle Ground Shoal A33 -14 as required by Administrative Approval AIO No. 9.008. The rate and pressure continue to indicate that there has been no change in the well's mechanical condition. Paul Figel Engineering Manager XTO Energy Inc. SCANNED PLAY {j 7 2013 Midland, TX Office: 432 - 620 -6743 Cell: 432 - 553 -5217 Fax: 432 - 687 -0862 0 • XTO Energy - A33 -14 (1670680) Rate and Pressure Monitoring Administrative Approval AIO No. 9.008 TBG Annulus [psig] 5,000 - WH Injection [psig] 1000 --+— Injection Rate (bbl /d) 4,500 900 Surface Casing Pressure 3 4,000 -0— 7" Intermed [psig] 800 co r n _ CL N d a 3,500 ' 700 Z C - 05 O co N y 3,000 6 a c _ d I m 2,500 5 00 I 2,000 1,500 300 v m Q ~ 1,000 200 N 500 100 0 -CTw w w w rw - -W. W - w wTw w w .Te .T. 3- 0 O 0 O 0 O ^ � O ^ � O 0 O ^1 < <1. 0 0 ^ O O O ^ O� N OE <1' 0 ^1' O O 1 \ ^ \ � 1 \� \ l' 4' '\Y A<1' 1 � ' \ � \` ^ \� 1' � \ � O ' \ \ 1 \ � \ \� ^ \� \� ry \% \ � O \ � \� ^ \ � 1 '1 1 1 ' 1 1 ' 1 '1 '1 1 • • A33-14 (1670680) Rate and Pressure Monitoring 10 -3/4" 7" TBG WH Injected Surf Intermed Annulus Injection Comments [bbl] [psig] [psig] [psig] [psig] Hrs Down 7/1/2012 478 8 6 3,450 3,500 0 7/2/2012 470 8 6 3,450 3,500 0 7/3/2012 462 8 6 3,450 3,500 0 7/4/2012 468 8 6 3,450 3,500 0 7/5/2012 460 6 6 3,475 3,500 0 7/6/2012 452 8 5 3,460 3,500 0 7/7/2012 416 8 5 3,460 3,500 0 7/8/2012 425 8 5 3,475 3,500 0 7/9/2012 418 8 5 3,475 3,500 0 7/10/2012 435 8 5 3,460 3,500 0 7/11/2012 428 10 5 3,460 3,500 0 7/12/2012 444 10 5 3,460 3,500 0 7/13/2012 443 7 5 3,460 3,500 0 7/14/2012 414 7 5 3,460 3,500 0 7/15/2012 417 7 5 3,460 3,500 0 7/16/2012 425 7 5 3,460 3,500 0 7/17/2012 404 7 5 3,460 3,500 0 7/18/2012 402 7 5 3,475 3,500 0 7/19/2012 404 10 8 3,475 3,500 0 7/20/2012 306 10 7 3,450 3,500 6 Pump Down 7/21/2012 473 10 7 3,450 3,500 0 7/22/2012 440 10 7 3,450 3,500 0 7/23/2012 436 10 7 3,450 3,500 0 7/24/2012 413 10 7 3,450 3,500 0 7/25/2012 418 10 7 3,475 3,500 0 7/26/2012 410 10 7 3,475 3,500 0 7/27/2012 411 10 7 3,475 3,500 0 7/28/2012 402 10 7 3,475 3,500 0 7/29/2012 402 10 7 3,475 3,500 0 7/30/2012 407 10 7 3,475 3,500 0 7/31/2012 409 10 7 3,475 3,500 0 ti XTO Energy - A33 -14 (1670680) Rate and Pressure Monitoring Administrative Approval AIO No. 9.008 TBG Annulus [psig] 1000 5000 WH Injection [psig] _ 4500 -- -- Injection Rate (bbl /d) 900 Surface Casing Pressure - • 4000 — 0 7 Intermed [psig] 8 as N - cc N d a 3500 - _ _.- _ _ , 700 ? 3000 • m `' I1 I l � - 60 _ MIPS b �►i A- ' i' `° 500 = • 2500 06 1 � - E N 400 2000 c Q 1500 • 4k. 300 c) n ♦ • ♦ - `t i 1000 200 N �! 4 - 500 • • 100 _ 1. - 0 - 0 ,,,I, 419 ,.\ V � 419 ► \ �O \19 , \ V ^\ V 4gy r \ gy p , \ gy p ,\ ,\ \ gy p ► \gy ►\ \ , L 9 ► \ gy p I\ \ , y 0 , \�, V 419 419 , 1 4 D. 4 c§ 1\ c: �� , ,,, ^ tip ^� ti 4 b' 4 c: A\ ct\ Regg, James B (DOA) PrD 1 4)7 6 03,c) From: Paul_Figel @xtoenergy.com `R 47I ( .z,, Sent: Thursday, July 12, 2012 7:49 AM To: Regg, James B (DOA); Scott_Griffith @xtoenergy.com; Barney_Phillips @xtoenergy.com; Greg_Duggin @xtoenergy.com; Schwartz, Guy L (DOA) Subject: XTO Energy - A33 -14 (1670680) Rate and Pressure Monitoring June 2012 AIO # 9 -008 Attachments: A33 -14 Rate and Pressure Monitoring June 2012 (AIO 9.008).xlsx Attached is the June 2012 in'ection ra ., • - • - - • • ressure monitori • - • • its for the Middle Ground Shoal A33 -14 as required by Administrative Approval AIO No. 9.008. The rate and pressure continue to indicate that there has been no change in the well's mechanical condition. SCANNED MAY a 7 2D13 Paul Figel Engineering Manager XTO Energy Inc. Midland, TX Office: 432 - 620 -6743 Cell: 432 - 553 -5217 Fax: 432 - 687 -0862 1 XTO Energy - A33 -14 (1670680) Rate and Pressure Monitoring Administrative Approval AIO No. 9.008 TBG Annulus [psig] 5000 1000 WH Injection [psig] —4.— Injection Rate (bbl /d) 4500 900 f Surface Casing Pressure d —e-- 7" Intermed [psig] y 3 4000 800 m to to _ z • d a ? c 3500 — — — — — — — _ - 70 ,� Y a) 3000 600 2 I f ° U d od 2500 11 ---�_� 500 In c ad Q 2 • 400 u rn t 3 F 1500 300 1000 200 500 100 0 e ` —_ - -- . . . . . . . . . - . . _-ra_ 0 • ANY '1,.' y o ,yo \tio \,yo \ti \ti \ti \ti M\ " ^ \ ,yo . V' \ yo \ ,yo \y o 6 � o 4 r0 6 Co ro C0 0 0 A33 -14 (1670680) Rate and Pressure Monitoring 10 -3/4" 7" TBG WH Injected Surf Intermed Annulus Injection Comments [bbl] [psig] [psig] [psig] [psig] Hrs Down 6/1/2012 398 5 2 3450 3500 0 6/2/2012 410 5 2 3450 3500 0 6/3/2012 415 5 2 3450 3500 0 6/4/2012 405 5 2 3450 3500 0 6/5/2012 414 5 2 3450 3500 0 6/6/2012 423 5 2 3450 3500 0 6/7/2012 419 5 2 3450 3500 0 6/8/2012 424 5 0 3460 3500 0 • 6/9/2012 410 5 0 3460 3500 0 6/10/2012 413 5 0 3460 3500 0 6/11/2012 437 5 0 3460 3500 0 6/12/2012 438 5 0 3460 3500 0 6/13/2012 435 5 0 3450 3500 0 6/14/2012 452 5 0 3475 3500 0 6/15/2012 457 5 0 3475 3500 0 6/16/2012 454 5 0 3450 3500 0 6/17/2012 453 5 0 3475 3500 0 6/18/2012 454 5 0 3475 3500 0 6/19/2012 458 5 0 3475 3500 0 6/20/2012 445 5 0 3475 3500 0 6/21/2012 457 9 4 3450 3500 0 6/22/2012 0 8 4 2900 2950 16 shut -in 6/23/2012 708 8 4 2900 2950 0 6/24/2012 532 8 5 3450 3500 0 6/25/2012 511 8 5 3450 3500 0 • 6/26/2012 515 8 5 3450 3500 0 6/27/2012 497 8 6 3450 3500 0 6/28/2012 495 8 6 3450 3500 0 6/29/2012 484 8 6 3450 3500 0 6/30/2012 486 8 6 3450 3500 0 7 XTO Energy - A33 -14 (1670680) Rate and Pressure Monitoring Administrative Approval AIO No. 9.008 TBG Annulus [psig] 5000 - 1000 WH Injection [psig] _ 4500 --• Injection Rate (bbl /d) 900 Surface Casing Pressure — 2 4000 0 7" Intermed [psig] 800 a.) 3 cn _ ce w - - . r . z a 3500 . 1111 1 - 700 z ' lr. MINI IN 3000 . ,. , 6 00 L 2 l I �1 � i: 1 , . l R 2500 - • � • 500 €3 2000 400 °r' 0,„ -3 111111.1111.1 Q 1500 300 .0 111111101.11111.1 tV3 H 1000 200 500 I 100 1 1111111111111111111111 �l • 0 - 0 A d o (yo 4P , X o ,yo do ,,,, , ,, P ,yo gi A • • titQS 14 Pb /6 70660 Regg, James B (DOA) 4 From: Paul_Figel @xtoenergy.com 7 Sent: Wednesday, June 06, 2012 6:43 AM 'gef�' 6 (I 2 To: Regg, James B (DOA); Scott_Griffith @xtoenergy.com; Barney_Phillips @ xtoenergy.com; Greg_Duggin @xtoenergy.com; Schwartz, Guy L (DOA) Subject: XTO Energy - A33 -14 (1670680) Rate and Pressure Monitoring May 2012 AIO # 9 -008 Attachments: A33 -14 Rate and Pressure Monitoring May 2012 (AIO 9.008).xlsx Attached is the May 2012 injection rate and wellhead pressure monitoring reports for the Middle Ground Shoal A33 -14 as required by Administrative Approval AIO No. 9.008. The rate and pressure continue to indicate that there has been no change in the well's mechanical condition. Paul Figel Engineering Manager XTO Energy Inc. Midland, TX Office: 432-620-6743 JUL 4 c 1 ZU1 Cell: 432 - 553 -5217 Fax: 432 - 687 -0862 1 . • • XTO Energy - A33 -14 (1670680) Rate and Pressure Monitoring Administrative Approval AIO No. 9.008 - - TBG Annulus [psig] 5,000 ->�WH Injection [psig] 1000 - +Injection Rate (bbl /d) 4,500 900 -R- Surface Casing Pressure - m - - 7" Intermed [psig] 800 y c 4,000 m N _ N -, d a 3,500 700 ? c aS o - v N u d 3.000 600 E a c - d 2,500 500 0 3 2,000 ♦ ♦ .-•-• 400 m c c °6 < 1,500 300 rn ' a - 1- c 1,000 200 500 100 0 C - - : . 3 0 Lo do 0 CS d o d o d o y o y o y o , y o y o y 0 , CS � S d o h \ ' h h `' h h \ CS< \` ^ \ '` 4 \'`4 \ ^ \ � 4 \ y 4 \ ti y \ \ tip \ \ 4 \ ti c \ h'` \ h h h h h h b h h h h • 0 A33 -14 (1670680) Rate and Pressure Monitoring 10 -3/4" 7" TBG WH Injected Surf Intermed Annulus Injection Comments [bbl] [psig] [psig] [psig] [psig] Hrs Down 5/1/2012 505 5 0 3,450 3,500 4 Pump down 5/2/2012 536 5 0 3,450 3,500 0 5/3/2012 485 5 0 3,450 3,500 0 5/4/2012 474 5 0 3,450 3,500 0 5/5/2012 449 5 0 3,450 3,500 0 5/6/2012 469 5 0 3,450 3,500 0 5/7/2012 442 5 0 3,450 3,500 0 5/8/2012 419 5 0 3,450 3,500 0 5/9/2012 476 5 0 3,450 3,500 0 5/10/2012 424 5 0 3,450 3,500 0 5/11/2012 355 5 0 3,450 3,500 4 Pump down 5/12/2012 405 5 0 3,450 3,500 2 Pump down 5/13/2012 409 5 0 3,450 3,500 0 5/14/2012 413 5 0 3,450 3,500 0 5/15/2012 411 5 0 3,450 3,500 0 5/16/2012 408 5 0 3,450 3,500 0 5/17/2012 409 5 0 3,450 3,500 0 5/18/2012 404 5 0 3,450 3,500 0 5/19/2012 398 5 0 3,475 3,500 0 5/20/2012 400 5 0 3,475 3,500 0 5/21/2012 411 5 0 3,475 3,500 0 5/22/2012 415 5 0 3,475 3,500 0 5/23/2012 413 5 0 3,475 3,500 0 5/24/2012 412 25 0 3,450 3,500 0 5/25/2012 427 5 2 3,450 3,500 0 5/26/2012 428 5 2 3,450 3,500 0 5/27/2012 425 5 2 3,460 3,500 0 5/28/2012 415 5 2 3,450 3,500 0 5/29/2012 394 5 2 3,450 3,500 0 5/30/2012 396 5 2 3,450 3,500 0 5/31/2012 394 5 2 3,450 3,500 0 XTO Energy - A33 -14 (1670680) Rate and Pressure Monitoring Administrative Approval AIO No. 9.008 —A— TBG Annulus [psig] 5000 - 1000 - WH Injection [psig] 4500 - — *-- Injection Rate (bbl /d) 900 -;- Surface Casing Pressure - • 4000 - 0 7 Intermed [psig] 800 co - ce a ci) a 3500 i - 700 I II CI � 600 3000 7 li �. illiffl,„ �i,� _ 0: ci) •c U iI! � • h i , :4', irl a z 2500 — � . �. �. �1• 500 05 II 2000 1 400 Q 1500 3 00 a> 1 J7 7 I- MEI 111111.11111111111111 1000 2 • 500 I 100 II 0 �O �O �O �O �O �O , �O , , �O , , �O ,�O , �O �O �O �O �O y 0 �O , �O � , ti 0 , , L O �O �O , �O , �O 1 O �O �O ,10 ^\ (19:0 � \ `1 „ \ `1 14 �\�\ \� \�\ �\ \,\ 541%\ ^,,p9,, � � \`'�\ :ef, , \y\ �\ \\ 0,4 � \, �\ 4 1' ;\ .�\ 4 < �\ 0\�\ r� �\ �\ �\ ^�\ ^�\ 0` �\ h h\ �° �\ '� '\\ �\ �\ �\ �\ �\ ► N • 4 \ ' N el.. r ` `L N N `L\ `L\ ")\ e p \ h <, G � ■ c • 1X7040 Regg, James B (DOA) From: Paul_Figel @xtoenergy.com `, I all Sent: Thursday, May 03, 2012 4:55 AM To: Re James B (DOA); Scott_Griffith xtoener com Barne _Philli s xtoener 99 , ( ) @ 9Y Y p @ 9Y com; n r .com; Schwartz, Guy L (DOA) Gre Du in xtoe e y ( 9_ 99 @ 9Y Rate and Pressure Monitoring A Subject: XTO Energy - A33-14 (1670680) Ra 9 p ril 2012 AIO # 9 -008 Attachments: A33 -14 Rate and Pressure Monitoring April 2012 (AIO 9.008).xls Attached is the April 2012 injection rate and wellhead pressure monitoring reports for the Middle Ground Shoal A33 -14 as required by Administrative Approval AIO No. 9.008. The rate and pressure continue to indicate that there has been no change in the well's mechanical condition. Paul Figel Engineering Manager ti. XTO Energy Inc. ELJUN 1 ZU1Z Midland, TX Office: 432 - 620 -6743 Cell: 432 - 553 -5217 Fax: 432 - 687 -0862 1 XTO Energy - A33 -14 (1670680) Rate and Pressure Monitoring Administrative Approval AIO No. 9.008 —A-- TBG Annulus [psig] 5000 - � WH Injection (psig] 1000 —4— Injection Rate (bbl /d) 4500 900 -— Surface Casing Pressure ` — 7" Intermed (psig] 0 :± 4000 80 ,2 co 0. 3500 x— '�ssszs —, w"'—-- — - — —. — 700 - C N O N d 3000 k 6 00 0` c Z = (0 5 00 m 06 E c m 2000 400 c 7 ao C Q 1500 300 8 lc R I- 3 I - 1000 200 r n 500 - 100 ti O4 ti oP.ti o^ ry �ti Do ti i 0 o bop 1t, b0 b0 bop 0 4 . aN , 1 , a\ ^ye ti • � a �0, a\ry � � � 0«ryop, . • • 6l' A33 -14 (1670680) Rate and Pressure Monitoring 10 -3/4" 7" TBG WH Injected Surf Intermed Annulus Injection Comments [bbl] [psig] [psig] [psig] [psig] Hrs Down 4/1/2012 0 5 0 2750 2850 24 Power failure 4/2/2012 13 5 0 2700 2800 22.5 Power failure 4/3/2012 549 5 0 3425 3500 0 4/4/2012 492 5 0 3450 3500 0 4/5/2012 469 5 0 3450 3500 0 4/6/2012 481 0 0 3400 3500 0 4/7/2012 524 0 0 3400 3500 0 4/8/2012 532 0 0 3400 3500 0 4/9/2012 433 0 0 3400 3500 4 4/10/2012 500 0 0 3400 3500 0 4/11/2012 503 0 0 3400 3500 0 4/12/2012 0 5 0 2775 2850 24 4/13/2012 158 5 0 3425 3500 15.5 4/14/2012 521 2 0 3450 3500 0 4/15/2012 507 2 0 3450 3500 0 4/16/2012 534 2 0 3450 3500 0 _ 4/17/2012 563 2 0 3450 3500 0 4/18/2012 587 2 0 3450 3500 0 4/19/2012 531 2 0 3450 3500 0 4/20/2012 569 2 0 3450 3500 0 4/21/2012 557 2 0 3450 3500 0 4/22/2012 547 2 0 3475 3500 0 4/23/2012 538 2 0 3475 3500 0 4/24/2012 526 2 0 3475 3500 0 4/25/2012 541 2 0 3475 3500 0 4/26/2012 528 5 0 3475 3500 0 4/27/2012 454 5 0 3450 3500 0 4/28/2012 478 5 0 3450 3500 0 4/29/2012 467 5 0 3450 3500 0 4/30/2012 24 5 0 2875 2900 23 Pump down XTO Energy - A33 -14 (1670680) Rate and Pressure Monitoring Administrative Approval AIO No. 9.008 -- -41- -TBG Annulus [psig] 5000 1000 WH Injection [psig] 4500 --•--- Injection Rate (bbl /d) 900 Surface Casing Pressure 3 4000 — 7" Intermed [psig] 800 co N d rt a 3500 -) ' 700 ? od 30 li �d ' �� . �. I�1`Iii ' m • lc I ► 111 `I C 600 a _ Ih �11 �, t I � r , °' 2 500 y_ TA! v —� i ' � I ' . . �. J) 500 06 1 tn 2000 ( ��I m 3 400 c Q 1500 300 v H co 1000 I 200 y 111 1 1 111 .1 111111111111111111111 ill • 5 00 �� ' j ' 100 �I �III I \ ,10 h \ ,\10 \ X10 \ �10 ,yo \1 ftt' �o ego \ ( 0 \ e f 4.0 \ tV <1 eg \ � o \ � O <"1. 41 tV \ 1r4V °°V \ � o ry o P#41;• \ , y o ry \ � o \ ry \ �o \ ry o mo o , '‘Z‘'• '.1'-'1, ry \' co‘' \'ti a \ \ \ti c 1:1, 1 \ A � \ -CO -C - ti p \ o \ ti ° N ` \ ti p \h \ \ - 1 °` \ ti h � e tih \ ' ` o \ti a \ti�h \` \'` N � 1 '3 b h o � o o o o ^ o N f N <1. r n' ti D� h prt 16 7 D66 • • ,, q Regg, James B (DOA) From: Paul_Figel @xtoenergy.com Sent: Monday, April 09, 2012 5:37 AM 4 Il Z'I v To: Regg, James B (DOA); Scott_Griffith @xtoenergy.com; Barney_Phillips @xtoenergy.com; Greg_Duggin @xtoenergy.com; Schwartz, Guy L (DOA) Subject: XTO Energy - A33 -14 (1670680) Rate and Pressure Monitoring Feb & Mar 2012 AIO # 9 -008 Attachments: A33 -14 Rate and Pressure Monitoring Feb & March 2012 (AIO 9.008).xls Attached is the Feb & March 2012 injection rate and wellhead pressure monitoring reports for the Middle Ground Shoal A33 -14 as require y dministrative Approval AIO No. 9.008. The rate and pressure continue to indicate that there has been no change in the well's mechanical condition. Paul Figel Engineering Manager XTO Energy Inc. Midland, TX Office: 432 - 620 -6743 Cell: 432 - 553 -5217 Fax: 432 - 687 -0862 4LANNEDAPR XTO Energy - A33 -14 (1670680) Rate and Pressure Monitoring Administrative Approval AIO No. 9.008 TBG Annulus [psig] 5000 - WH Injection [psig] 1000 — ♦-- Injection Rate (bbl /d) 4500 - 900 Surface Casing Pressure —0 7" Intermed [psig] 800 °' • % 4000 CO _ Ce a 3500 , , T T )— 700 ? c _ 0 0 N 3000 600 L c - = 2500 500 - 1 a m 06 1 Cl) 2000 400 c Q 1500 300 8 - - `t ~ • 1000 200 500 100 7 1 0 Cw -- _ 3 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 F.0 FA 0 0 0 0 F.0 0 0 XTO Energy - A33 -14 (1670680) Rate and Pressure Monitoring Administrative Approval AIO No. 9.008 TBG Annulus [psig] 5000 - 1000 WH Injection [psig] — 4500 ---*-- Injection Rate (bbl /d) 900 Surface Casing Pressure — L 4000 0 7 Intermed [psig] 800 a) • co ca co — ce a) a 3500 .. . , ___ ___ -- - e . 700 II L ? ' - �S Cn V 3000 ! r i', 600 a> � a a) = 2500 '► Atli : ' 500 1 I II, - E = 2000 400 c - c • Q 1500 • • • 300 c) .a • ♦ - = ♦ 1- 1000 200 � • 500 ♦ • i — 100 0 0 —N \� \� \ gyp \ � p D \ � p 4 \ � p `1�� 0 \ � O \ � O \ � O '� \ � O R \�0� \�Oh \� O� \�O"� \r�0 q9. \cf \� . \�. � \�. \ \►� .� \, \ ►�, ` \ "� \� \ 1, \►� \ 1, , � ^1 \,,, ,,p , N \ `L \'� , `L n p .p, p\ t.,1, • • Regg, James B (DOA) From: Paul_Figel @xtoenergy.com Sent: Monday, February 20, 2012 8:03 AM �rJ�f �, To: Regg, James B (DOA); Scott_Griffith @xtoenergy.com; Barney_Phillips @xtoenergy.com; Greg_Duggin @xtoenergy.com; Schwartz, Guy L (DOA) Subject: XTO Energy - A33 -14 (1670680) Rate and Pressure Monitoring Jan 2012 AIO # 9 -008 Attachments: A33 -14 Rate and Pressure Monitoring Jan 2012 (AIO 9.008).xls 1 4� I I Attached is the Jan 2012 injection rate and wellhead pressure monitoring reports for the Middle Ground Shoal A33 -14 as required by Administrative Approval AIO No. 9.008. The rate and pressure continue to indicate that there has been no change in the well's mechanical condition. Paul Figel Engineering Manager XTO Energy Inc. Midland, TX Office: 432 - 620 -6743 Cell: 432 - 553 -5217 Fax: 432 -687 -0862 +� 2 1 li - • • XTO Energy - A33 -14 (1670680) Rate and Pressure Monitoring Administrative Approval AI® No. 9,008 --A— TBG Annulus [psig] 5000 —.-- WH Injection [psig] 1000 —0— Injection Rate (bbl /d) 4500 900 ---- Surface Casing Pressure 3 4000 7" Intermed [psig 800 m is N a' a` 3500 ;� ." ;: _ 700 K o N m 3000 600 i C Ili a It 2500 500 -a 05 d E 3 2000 400 1 3 c c ad < 1500 300 8 .0 t ~ 1000 200 rn 500 100 0 0 Nti ^ti Nry NI' < Nti NI' N• <V Nti �ti 4� ^ry �ti Ng' 1 ' 41 ' , e P 49' , , , , , ,1 r10 '19' , , ■ , 1 0 , ,10 • • A33 -14 (1670680) Rate and Pressure Monitoring 10 -3/4" 7" TBG WH Injected Surf Intermed Annulus Injection Comments [bbl] [psig] [psig] [psig] [psig] Hrs Down 1/1/2012 494 2 0 3125 3150 8 1/2/2012 300 2 0 3450 3500 15 1/3/2012 566 2 0 3350 3350 4 1/4/2012 699 2 0 3425 3500 0 1/5/2012 660 2 0 3400 3500 0 1/6/2012 589 2 0 3425 3500 0 1/7/2012 610 2 0 3425 3500 0 1/8/2012 546 2 0 3425 3500 0 1/9/2012 540 2 0 3425 3500 0 1/10/2012 557 2 0 3425 3500 0 1/11/2012 510 2 0 3450 3500 0 1/12/2012 508 2 0 3450 3500 0 1/13/2012 512 2 0 3450 3500 0 1/14/2012 510 2 0 3450 3500 0 1/15/2012 507 2 0 3450 3500 0 1/16/2012 501 2 0 3450 3500 0 1/17/2012 444 2 0 3450 3500 3 1/18/2012 0 2 0 3450 3500 24 turbine down 1/19/2012 0 2 0 2700 2700 24 turbine down 1/20/2012 5 2 0 2625 2625 24 turbine down 1/21/2012 686 2 0 3440 3450 0 1/22/2012 480 2 0 3450 3500 0 1/23/2012 572 2 0 3450 3500 0 1/24/2012 532 2 0 3450 3500 0 1/25/2012 534 2 0 3450 3500 0 1/26/2012 552 2 0 3450 3500 0 1/27/2012 537 2 0 3450 3500 0 1/28/2012 482 2 0 3450 3500 0 1/29/2012 253 2 0 3450 3500 12 1/30/2012 0 2 0 2750 2750 24 1/31/2012 0 2 0 2650 2675 24 I • • XTO Energy - A33 -14 (1670680) Rate and Pressure Monitoring Administrative Approval AIO No. 9.008 5000 -- TBG Annulus [psig] 1000 =4 WH Injection [psig] 4500 —.,— Injection Rate (bbl /d) 900 —2— Surface Casing Pressure 4000 —6- Intermed [psig] 800 m as ca N 2 600 m 3500 - � — t ,.. . i l 700 ? I i 1 '1' ,11 3000 ii i I � l�. 2500 q 7� ,..,..s.„ II • ` � 500 2000 T IL I I !k1 I �� LI 400 . ea 1500 lllliil 1 1�I111 300 co 100a � IIIII�!! iIIII 200 500 1111 -111111100 ry o� , y 0� ry o ryo ryo� l o b 1, ,,0 ryo x ,10 4 ,104 \ ,I0 ,,O � �^ t. ._,O, ^ 41. 4" .3\'' 0�0 o�ti� h ,., 6 �e 41 1\ti A\ A\ ��",0 e� \^0 o �'b ` � ^ N <% ^ , y \'• ^ , I P ^ N 4.1' • • sctigisE DT ALAsEn/ SE AN PARNELL, GOVERNOR r ALASKA Out AND GAS 333 W. 71hAVENUE, SUITE 144 CONSERVATION COM IISSION ANCHORAGE ALASKA 99501-3539 PHONE (907) 279 -1433 FAX (907) 276 -7542 AMENDED ADMINISTRATIVE APPROVAL AREA INJECTION ORDER 9.008 Mr. Paul Figel Engineering Manager XTO Energy AdMIED MAR 1 'all 200 North Loraine, Suite 800 Midland, TX 79701 RE: MGS A33 -14 (PTD 1670680) Administrative Approval Revision Middle Ground Shoal (MGS) E, F, G Oil Pool Dear Mr. Figel: In accordance with Rule 6 of Area Injection Order (AIO) 09.000, the Alaska Oil and Gas Conservation Commission (AOGCC or Commission) hereby GRANTS XTO Energy's (XTO)'s August 12, 2010 request for administrative approval to continue water injection in the subject well. The Commission further amends this approval to clarify that testing of the well shut- in equipment linked to the well's outer annulus pressure includes both the shut -down valve and the mechanical or electrical pressure detection device. Middle Ground Shoal (MGS) A33 -14 exhibits tubing by inner annulus communication, The Commission finds that XTO does not intend to perform repairs at this time, deferring until a rig workover can be justified. Reported results of XTO's diagnostic procedures and wellhead pressure trend plots indicate that MGS A33 -14 exhibits at least two competent barriers to the release of well pressure. It is expected that the inner annulus pressure will equalize with the injection pressure. When equalized the surface pressure of 3500 psi will be approximately 57 % of the production casing's minimum internal yield pressure rating. Should the well develop communication to the outer annulus, the 3500 psi injection pressure would represent 117 % of the surface casing's minimum internal yield pressure rating. Outer annulus pressures must be monitored and engineering controls must be installed to assure ongoing integrity of the surface casing. With such in place, the Commission believes that the well's condition would not compromise overall well integrity so as to threaten human safety or the environment. AOGCC's administrative approval to continue water injection only in MGS A33 -14 is conditioned upon the following: 1. Injection is limited to WATER ONLY. • • A10 9.008 (Amended) November 1, 2010 Page 2 of 3 2. XTO shall monitor and record tubing, inner annulus and outer annulus (TII/O) pressures and injection rate daily; 3, XTO shall submit to the AOGCC a monthly report of well pressures, injection rates, and pressure bleeds for all annuli; 4. Due to mechanical risk, a pressure test of the combined tubing and inner annulus (CHIT) is NOT required; 5. XTO shall perform a MIT -OA to 500 psi every 2 years; 6. XTO shall install, maintain and operate automatic well shut -in equipment linked to the well's outer annulus pressure. The actuation pressure shall not exceed 300 psi, Testing of the shut-in equipment (shut -down valve and mechanical or electrical pressure detection device) shall be performed in conjunction with production well pilots and safety valves. XTO shall provide to the Commission the testing procedure that will be used to verify the integrity of the well shut -in equipment linked to the outer annulus pressure; 7. XTO shall immediately shut in the well and notify the AOGCC if there is any change in the well's mechanical condition; 8, After well shut in due to a change in the well's mechanical condition, AOGCC approval shall be required to restart injection; and 9. The initial OA MIT should be performed in conjunction with the shut -in e•. ".ant testing requirement of Rule 6. That will establish the anniversar date for f t N at j` ? e, Alaska and dated November 1, 2010 �_ ._ i I 4_. • i L �( i aniel T. Se • ount, Jr. Cath,. P. Foerster , '� .�,*:! • a Chair, Co I 'ssioner Commissioner I , ner fiIs .4. y ihil RECONSIDERATION AND APPEAL NOTICE As provided in AS 31.05.080(a), within 20 days after written notice of the entry of this order or 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 of the matter determined by it. If the notice was mailed, then the period of time shall be 23 days. An application for reconsideration must set out the respect in which the order or decision is believed to be erroneous. 'fhe Commission shall grant or refuse the application for reconsideration in whole or in part within 10 days after it is filed. Failure to act on it within 10 -days is a denial of reconsideration. If the Commission denies reconsideration, upon denial, this order or decision and the denial of reconsideration are FINAL, and may be appealed to superior court. The appeal MUST be filed within 33 days after the date on which the Commission mails, OR 30 days if the Commission otherwise distributes, the order or decision denying reconsideration, UNLESS the denial is by inaction, in which case the appeal MUST he filed within 40 days after the date on which the application for reconsideration was filed. If the Commission grants an application for reconsideration, this order or decision does not become final. Rather, the order or decision on reconsideration will be the FINAL order or decision of the Commission, and it may be appealed to superior court. That appeal MUST be filed within 33 days after the date on which the Commission mails, OR 30 days if the Commission otherwise distributes, the order or decision on reconsideration. As provided in AS 31.05.080(b), "[tike questions reviewed on appeal are limited to the questions presented to the Commission by the application for reconsideration." In computing a period of time above the date of the event or default after which the designated period begins to tun is not included in the period, the last day of the period is included, unless it falls on a weekend or state holiday, in which event the period runs until 5:00 p.m. on the next day that does not fall on a weekend or state holiday Page 1 of 1 Maunder, Thomas E (DOA) From: Paul_Figel @xtoenergy.com Sent: Friday, October 29, 2010 4:56 AM To: Maunder, Thomas E (DOA) Subject: Re: XTO MGS CO -23 and A33 -14 Ok. Paul "Maunder, Thomas E (DOA)" To Paul_Figel @xtoenergy.com, Scott_Griffith @xtoenergy.com, <tom.maunder @alaska.gov> Greg_Duggin @xtoenergy.com cc Barney_Phillips @xtoenergy.com, "Noble, Robert C (DOA)" 10/28/2010 06:15 PM <bob.noble @alaska.gov> Subject XTO MGS C42 -23 and A33 -14 Paul, et al, Due to some questions on other wells where similar annular pressure pilots and SSV's have been installed, the following clarification is provided. It is the Commission's expectation that when routinely tested (6 month interval) that the complete SVS system (pilot and valve) will be tested. In order to be sure of this expectation, the Administrative Approvals will likely be reissued with this clarification. Call or message with any questions. Tom Maunder, PE AOGCC 2/18/2011 • • Page 1 of 1 Maunder, Thomas E (DOA) From: PauI_Figel @xtoenergy.com Sent: Tuesday, October 26, 2010 10:59 AM To: Maunder, Thomas E (DOA) Subject: A33 -14 (167 -068) Attachments: A33 -14 WellHead.pdf Tom, Here's the corrected version. Sorry for the confusion. Paul Figel Engineering Manager XTO Energy Inc. Midland, TX Office: 432 - 620 -6743 W NOV 0 2 Cell: 432 - 553 -5217 Fax: 432 - 687 -0862 I i 10/26/2010 41 4 + a t .• � 3„� "� _ ^.� �� h^�� y r, � f y �'.. p ( +j _ , •� t A x r i 6 � - n Ism ow- k o ,_ As I i Ito 5SY htett k33 - 11, NA I A- S�sfin FS s+� 3QO PSI Page lof2 Maunder, Thomas E (DOA) From: Maunder, Thomas E(OOA) Sent: Tuaoduy, October 26, 2010 7:51 AM To: 'Pou|_Fige|@xtoenergy.00m' Co: Bonney_PhiUipoKDxboenergy.00m; Noble, Robert C(OOA);Cody_Mish|ar@xtoenergy.00m; Greg Du0Ain@xtoanergy.com; Scott Grifflth@xb»enerQy.00m;8beve_Phipps@xdomnergy.com Subject: RE: A33-14(1G7-OG8) piping changes Probably best toreoond with correct names. From: Pau[_Fige|@xtoenengy.conm [nnai|to:Pau|_Fige|@xtoene»gy.00m] Sent: Tuesday, October 26,2D1O7:49AM To: Maunder, Thomas E(DOA) Cc: Barney_Phi||ips@xboenengy.conn; Noble, Robert C[DOA); Cody_Miah|er@xtoene»gy.com; � Greg_Duggin@xtoenengy.00m;Scott_Griffith@xtoenergy.conn;Steve-Phippy@xtoenergy.conn Su���«�: RE' A33 1� pipingchangeu /167 O68\ � -~ . ' ` - ^ Tom, The original e-mail was incorrect. This is well A33-14 not A33-11. Steve labeled the pictures wrong. Should we paumnd pictures m/ correct well #? Paul ^Muunue,. Thomas s(nou)^ To wmm.muunuur@a/asm,.envp po"LF/oe/@xmonergv.uom.nteve-pmnno@moenergv.uom cuowu m|nmo .s | rgy.c*m. nm,tt-G,/ffim@mvonomy.vum.00mex_pmmpx@avonorgy.uvm.^wumo. 10/25/2010 05:38 Pm Robert c(oo*)^<uuuoumo@o|ov:a.onv' Subject RE: A33'11 (1oo'000) piping changes Thanks Paul. Looks good. A000rdingtotha|astemai||axohangedvvithBarney(10/15).an|nspectorwi||be onboard -11/11 for 8VS testing and the Outer Annulus (O/\) pressure shutdowns on /\33'11 and C24-23 will be tested then as vve||. Also a request; when a specific well in the subject of meonage, please include the permit to drill number in the subject line oo| have above. Since this well also has a lateral, itia only necessary toinclude the PTDof the motharbore. Call or message with any questions. Tom Maunder, PE AOGCC From: Pau[Fige|@xtoenergy.conn[nnai|to:Pau[Fige|@xtoenergy.conn] Sent: Monday, October 25, 2010 2:20 9M lU/2b/2UI0 0 0 Page 2 of 2 To: Steve_Phipps @xtoenergy.com; Maunder, Thomas E (DOA) Cc: Cody_Mishler @xtoenergy.com; Greg_Duggin @xtoenergy.com; Scott—Griffith@xtoenergy.com Subject: Re: A33 -11 piping changes Steve, Should be good to go as AOGCC as given permission as of Sept 13th. Paul Figel Engineering Manager XTO Energy Inc. Midland, TX Office: 432 - 620 -6743 Cell: 432 - 553 -5217 Fax: 432 - 687 -0862 Steve Phipps /KEN /CTOC 10/25/2010 04:28 PM To Paul Figel /MID /CTOC @CTOC CC Greg Duggin /KEN /CTOC @CTOC, Scott Griffith /KEN /CTOC @CTOC, Cody Mishler /KEN /CTOC @CTOC Subject A33 -11 piping changes Paul, We have completed the piping changes on -11. I have enclosed pictures of the well once the work was completed. We are just waiting on approval from you and the state to start injecting. Steve Phipps Operations Supervisor XTO Energy, Inc. 52260 Wik Road Kenai, AK 99611 907 - 398 -6474 10/26/2010 Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Frida Y, October 15, 2010 2:56 PM To: ' Barney_Phillips @xtoenergy.com'; Paul_Figel @xtoenergy.com Cc: Noble, Robert C (DOA) Subject: RE: XTO Energy - C24 -23 Rate and Pressure Monitoring Sept 2010 AIO # 9- Thanks Barney, Yes, please test the annular pilots with the safety val T hat will become pretty normal now. Call or message with any questions. Tom Maunder, PE AOGCC.��(� P� -- Original Message---- - From: Barney_ Phillips @xtoenergy.com [mailto: Barney _Phillips @xtoene-Lgy.cmi Sent: Friday, October 15, 2010 11:15 AM To: Paul_Figel @xtoenergy.com Cc: Maunder, Thomas E (DOA) Subject: RE: XTO Energy - C24 -23 Rate and Pressure Monitoring Sept 2010 AIO # 9 -007 Paul / Tom, We do not have another scheduled MIT due until 11/2011. Bob Noble (AOGC) is scheduled to be on board 11/11 and 11/12/2010 for 180 day cycle SVS tests. Would be happy to test these pilots while Bob is here for him to witness if you like. These pilots / actuators are easy to test and only requires shutting in injection for a short period of time. Barney Phillips barney_phillips @xtoenergy.com Platform A: 907 - 776 -5241 Platform C: 907 - 776 -5251 �0 Iv Paul Figel /MID /CTOC To 10/08/2010 07:38 "Maunder,.Thomas E (DOA)" AM <tom.maunder @alaska.gov >, Barney Phillips /KEN /CTOC @CTOC cc Subject RE: XTO Energy - C24 -23 Rate and Pressure Monitoring Sept 2010 AIO # 9- 007(Document link: Barney Phillips) Barney, 1 Please provide Tom with answer. • Thanks, Paul "Maunder, Thomas E (DOA) " <tom.maunder @alas To ka.gov> Paul_Figel @xtoenergy.com cc 10/08/2010 10:33 AM Subject RE: XTO Energy - C24 -23 Rate and Pressure Monitoring Sept 2010 AIO # 9 -007 When is the next set of normal MITs scheduled out there? From: Paul_Figel @xtoenergy.com ( mailto :Paul_Figel @xtoenergy.com] Sent: Friday, October 08, 2010 6:29 AM To: Maunder, Thomas E (DOA) Subject: RE: XTO Energy - C24 -23 Rate and Pressure Monitoring Sept 2010 AIO # 9 -007 Yes it was. It was Rule 6. We will combine Rule 5 at the same time. Paul "Maunder, Thomas E (DOA)" <tom.maunder @alaska.gov> To 10/08/2010 08:50 AM Paul_Figel @xtoenergy.com cc Subject RE: XTO Energy - C24 -23 Rate and Pressure Monitoring Sept 2010 AIO # 9 -007 2 ! • Morning Paul, I thought the testing requirement was included in the administrative approval. Tom From: Paul_Figel @xtoenergy.com [ mailto :Paul_Figel @xtoenergy.com] Sent: Fri 10/8/2010 4:38 AM To: Maunder, Thomas E (DOA); Barney_Phillips @xtoenergy.com Cc: Greg_Duggin @xtoenergy.com; Regg, James B (DOA); Scott_Griffith @xtoenergy.com Subject: RE: XTO Energy - C24 -23 Rate and Pressure Monitoring Sept 2010 AIO # 9 -007 Tom, The A33 -14 has been SI since Aug. The wellhead work should be done by next week & then s ould be back on inj. Good idea for the testing. Barney Phillips is in charge of the SV & MIT testing. Paul "Maunder, Thomas E (DOA)" <tom.maunder @alaska.gov> 10/07/2010 06:00 PM To Paul_Figel @xtoenergy.com cc Scott_Griffith @xtoenergy.com, Greg_Duggin @xtoenergy.com, "Regg, James B (DOA)" <jim.regg @alaska.gov> Subject RE: XTO Energy - C24 -23 Rate and Pressure Monitoring Sept 2010 AIO # 9 -007 Thanks Paul. I presume the similar report for the Platform A well is coming. I don't know the SVS test schedule, however both pilots should be tested if possible when the safety valves are tested. Alternately, if there is an MIT the test can be accomplished then. Regards, Tom Maunder, PE AOGCC 3 From: Paul_Figel @xtoenergy.com [mailto:Paul_Figel @xtoenergy.com] Sent: Thursday, October 07, 2010 11:21 AM To: Maunder, Thomas E (DOA); Regg, James B (DOA) Cc: Scott_Griffith @xtoenergy.com; Greg_Duggin @xtoenergy.com Subject: XTO Energy - C24 -23 Rate and Pressure Monitoring Sept 2010 AIO # 9 -007 Attached is the Sept 2010 injection rate and wellhead pressure monitoring reports for the Middle Ground Shoal C24 -23 as required by Administrative Approval AIO No. 9.007. The rate and pressure continue to indicate that there has been no change in the well's mechanical condition. The outer annulus pressure sensor was installed on Sept 26th that will SI the injection if the OA press hits 300 psi. Please contact me with any questions. tions. Paul Paul Figel Engineering Manager XTO Energy Inc. Midland, TX Office: 432 - 620 -6743 Cell: 432- 553 -5217 Fax: 432 - 687 -0862 4 • • scErniT1 cy nitnsE SEAN PARNELL, GOVERNOR ALASKA. OIL AND GAS 333 W. 7th AVENUE, SUITE 100 CONSERVATION COMMISSION ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 ADMINISTRATIVE APPRO AL FAx (9 07) 276-7542 Area Injection Order 9.008 Mr. Paul Figel =t Engineering Manager XTO Energy 200 North Loraine, Suite 800 Midland, TX 79701 RE: MGS A33 -14 (PTD 1670680) Administrative Approval Revision Middle Ground Shoal (MGS) E, F, G Oil Pool Dear Mr. Figel: In accordance with Rule 6 of Area Injection Order ( "AIO ") 09.000, the Alaska Oil and Gas Conservation Commission (AOGCC or Commission) hereby GRANTS XTO Energy's (XTO)'s August 12, 2010 request for administrative approval to continue water injection in the subject well. Middle Ground Shoal (MGS) A33 -14 exhibits tubing by inner annulus communication, The Commission finds that XTO does not intend to perform repairs at this time, deferring until a rig workover can be justified. Reported results of XTO's diagnostic procedures and wellhead pressure trend plots indicate that MGS A33 -14 exhibits at least two competent barriers to the release of well pressure. It is expected that the inner annulus pressure will equalize with the injection pressure. When equalized the surface pressure of 3500 psi will be approximately 57 % of the production casing's minimum internal yield pressure rating. Should the well develop communication to the outer annulus, the 3500 psi injection pressure would represent 117 % of the surface easing's minimum internal yield pressure rating. Outer annulus pressures must be monitored and engineering controls must be installed to assure ongoing integrity of the surface casing. With such in place, the Commission believes that the well's condition would not compromise overall well integrity so as to threaten human safety or the environment, AOGCC's administrative approval to continue water injection only in MGS A33 -14 is conditioned upon the following: I . Injection is limited to WATER ONLY. 2. XTO shall monitor and record tubing, inner annulus and outer annulus (T /I /O) pressures and injection rate daily; s • AIO 9.008 September 13, 2010 Page 2 of 2 3. XTO shall submit to the AOGCC a monthly report of well pressures, injection rates, and pressure bleeds for all annuli; 4. Due to mechanical risk, a pressure test of the combined tubing and inner annulus (OMIT) is NOT required; 5. XTO shall perform a MIT -OA to 500 psi every 2 years; 6. Within 60 days of the effective date of this approval, XTO shall install, maintain and operate automatic well shut -in equipment linked to the well's outer annulus pressure. The actuation pressure shall not exceed 300 psi. Testing of the shut -in equipment shall be performed in conjunction with production well pilots and safety valves; 7. XTO shall immediately shut in the well and notify the AOGCC if there is any change in the well's mechanical condition; 8. After well shut in due to a change in the well's mechanical condition, AOGCC approval shall be required to restart injection; and 9. The initial OA MIT should be performed in conjunction with the shut -in equipment testing requirement of Rule 6. That will establish the anniversary date for future t- Litt G DONE at Anchorage, Alask • • : to • = . e mber 13, 2010. oaf b i - Daniel T. Seamount � + :rman Cath P. Foerster r:t}�IIdx Chair, Commissioner Commissioner — Commissioner RECONSIDERATION AND APPEAL NOTICE As provided in AS 31.05.080(a), within 20 days after written notice of the entry or this order or 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 of the matter determined by it If the notice was mailed, then the period of time shall be 23 days. An application for reconsideration must set out the respect in which the order or decision is believed to be erroneous. The Commission shall grant or refuse the application for reconsideration in whole or in part within 10 days after it is filed Failure to act on it within 10 -days is a denial of reconsideration If the Commission denies reconsideration, upon denial, this order or decision and the denial of reconsideration are FINAL and may be appealed to superior court_ The appeal MUST be filed within 33 days after the date on which the Commission mails, OR 30 days if the Conunission otherwise distributes, the order or decision denying reconsideration, UNLESS the denial is by inaction, in which case the appeal MUST be filed within 40 days after the date on which the application For reconsideration was filed. If the Commission grants an application for reconsideration, this order or decision does not become final, Rather, the order or decision on reconsideration will be the FINAL order or decision of the Commission, and it may be appealed to superior court. That appeal MUST be filed within 33 days after the date on which the Commission mails, OR 30 days if the Commission otherwise distributes, the order or decision on reconsideration. As provided in AS 31.05.080(b), "jtlhe questions reviewed on appeal are limited to the questions presented to the Commission by the application for reconsideration." In computing a period of time above, the date of the event or default after which the designated period begins to run is not included in the period; the last day of the period is included, unless it falls on a weekend or state holiday, in which event the period runs until 5:00 p.m. on the next day that does not fail on a weekend or state holiday. Pagelof2 Maunder, Thomas E (DOA) From: Paul_Figel @xtoenergy.com Sent: Monday, September 13, 2010 5:44 AM To: Maunder, Thomas E (DOA) Subject: RE: XTO A33 -14 Press Comm Attachments: C24 -23 Wellhead.pdf Tom, Here's the set up for the wellhead. Paul "Maunder, Thomas E (DOA)" To <tom.maunder@alaska.gov> Paul_Figel @xtoenergy.com cc 09/10/2010 11:17 AM Subject RE: XTO A33 -14 Press Comm Thanks much. I misunderstood that there also would be some sort of relief capability in addition to the pilot and valve. With the drawing, I will be able to get the revision for C24 -23 out and then A33 -14 can soon follow. Thanks again for iterating with the information. Tom Maunder, PE AOGCC From: Paul_Figel @xtoenergy.com [mailto:Paul_Figel @xtoenergy.com] Sent: Friday, September 10, 2010 7:49 AM To: Maunder, Thomas E (DOA) Subject: RE: XTO A33 -14 Press Comm Tom, The pressure sensor will be located on the 10 -3/4" x 7" annulus. There is not a relief valve on the IA. It will be air automated valve (SSV) that is installed on the injection tbg that will close when the pressure sensor on the OA hits 300 psi that will halt injection. They are sending me a quick sketch this afternoon that should clarify this. 2/18/2011 � � ate.► solo • • • to‘iscf;)‘‘, • N E��: , :' ',% 0 . • • • Page 2 of 2 Paul "Maunder, Thomas E (DOA)" <tom.maunder @alaska.gov> To Paul_Figel @xtoenergy.com 09/09/2010 01:56 PM cc Subject RE: XTO A33 -14 Press Comm Hi Paul. I do appreciate what you all are doing here. I cannot tell you what to do and while we have been discussing diagnostic testing, any operation is XTO's decision to conduct. I understand your concerns and there is risk of junking the well. I believe I have sufficient information in order to write the AA. It appears that A33 -14 will essentially be similar to C24 -23 where it is not possible to set a WL plug for the combo MIT. C24 -23 has been unenterable for over 15 years. Only other item is regarding the "drawing ". It doesn't have to be fancy, but it would help to see how the installation will be set up. I know the SSV is on the flowline to the well and the pilot (set at 300 psi) is on the OA. I presume the actual relief valve will be on the IA. Is this a pop -off type relief or will the pilot activation also be in control here? Tom Maunder, PE AOGCC From: Paul_Figel @xtoenergy.com [ mailto :Paul_Figel @xtoenergy.com] Sent: Thursday, September 09, 2010 5:44 AM To: Maunder, Thomas E (DOA) Subject: XTO A33 -14 Press Comm Tom, Attached are the notes on how the well reacted when trying to bleed down. We are concerned getting down with the tools if the tbg is parted. It might be better to drop a "N" test tool downhole to pressure up on assuming there is not scale obstructing from going to bottom. Let me know if there is something else to discuss. Thanks, Paul Paul Figel Engineering Manager XTO Energy Inc. Midland, TX Office: 432 - 620 -6743 Cell: 432 - 553 -5217 Fax: 432 - 687 -0862 2/18/2011 • • A33-14 — Bleed Down Tests 9/6/2010 10:40 Hook up 1 /2" jumper line from annulus 5" casing to production header. Start bleeding sown annulus. Tubing 2500 PSI / Annulus 2500 PSI. 11:20 Annulus down to 100 PSI. Still moving fluid to production header. Tubing PSI down to 2100. Due to communication, well appears to be flowing tubing to annulus to production header. Shut in jumper hose from annulus to header. Start moving bleed off hose to tubing — tree cap. 11:30 Noted that annulus had already built up to 2000 PSI. Tubing was at 2150. 11:40 Start bleeding down tubing through 1 /2" jumper hose to production header. Tubing and annulus both at 2175 PSI. 12:40 Tubing and annulus both at 1750 PSI. 13:40 Tubing and annulus both at 1600 PSI. Shut off jumper hose. 13:45 Tubing and annulus both built up to 2050 PSI. 14:00 Tubing and annulus both built up to 2125 PSI. 9/7/2010 07:00 Tubing and annulus both at 2450 PSI. • Page 1 of 2 Maunder, Thomas E (DOA) From: Paul_Figel @xtoenergy.com Sent: Friday, September 03, 2010 10:34 AM To: Maunder, Thomas E (DOA) Cc: Greg_Duggin @xtoenergy.com; Scott_Griffith@xtoenergy.com Subject: RE: XTO Energy - C24 -23 Rate and Pressure Monitoring Aug 2010 AIO # 9 -007 Attachments: A33 -14 Rate and Pressure Monitoring AUG 2010.xls Tom, Here's the data A33 -14. I was told we have the SSV valves for A33 -14 & C24 -23 but the press relief valves were 2 weeks out. They thought we should have everything installed before the end of the month. They were going to get you pictures once completed for both wells. Paul Figel Engineering Manager XTO Energy Inc. Midland, TX Office: 432 - 620 -6743 CeII: 432- 553 -5217 Fax: 432 - 687 -0862 "Maunder, Thomas E (DOA)" To <tom.maunder @alaska.gov> Paul_Figel @xtoenergy.com, "Regg, James B (DOA)" <jim.regg @alaska.gov> cc Scott_Griffith @xtoenergy.com, Greg_Duggin @xtoenergy.com 09/03/2010 10:41 AM Subject RE: XTO Energy - C24 -23 Rate and Pressure Monitoring Aug 2010 AIO # 9- 007 Thanks Paul. Do you have similar information for A33 -14? I am working to revise AIO 9.007 and the new AA for A33 -14. How goes the schedule for the pilots and SD valves? Tom Maunder, PE AOGCC From: Paul_Figel @xtoenergy.com [ mailto :Paul_Figel @xtoenergy.com] Sent: Friday, September 03, 2010 6:46 AM To: Maunder, Thomas E (DOA); Regg, James B (DOA) Cc: Scott_Griffith @xtoenergy.com; Greg_Duggin @xtoenergy.com Subject: XTO Energy - C24 -23 Rate and Pressure Monitoring Aug 2010 AIO # 9 -007 ocit a 2/18/2011 • Page 2 of 2 Attached is the Aug 2010 injection rate and wellhead pressure monitoring reports for the Middle Ground Shoal C24 -23 as required by Administrative Approval AIO No. 9.007. The rate and pressure continue to indicate that there has been no change in the well's mechanical condition. Please contact me with any questions. Paul Figel Engineering Manager XTO Energy Inc. Midland, TX Office: 432 - 620 -6743 CeII: 432 - 553 -5217 Fax: 432 - 687 -0862 2/18/2011 4 11 111 XTO Energy - A33 -14 Rate and Pressure Monitoring 5,000 1,000 ""11•••CsgxTbg Annulus Pressure •10 Injection Pressure 900 4,500 'Injection Rate (bbl /d) d Surface Casing Pressure 4,000 800 as N • d a ` o 3,500 700 o U m 3,000 600 ,5 3 2,500 war — ww -- — - 500 N F. C • 2,000 400 0 rn w sa K 1,500 300 0 rn N N U 1,000 200 5 y 500 100 0 0 ^ O . �o ^ O ^ o ^ O ^ O ^ O .�O ^ o ^ O . ^ O ■ O ^ O ,� ^ O ^ O e ^ O ^ O 17 \ \ 1 " \ , 1 0 7 \ 17 7 A \11, \ , y o \,yo \ 17 \ 17 17 fr \ , 1 0 \ , l o 's . 0 ' \ " A \ A \M A \ y ` \ A \ A \N^ A \N A \N A \ ^ A \N '0 A A A \ '0 1 \ry9 ^ o \ L b ct 0 \ �� ^ O XTO Energy - A33 -14 Rate and Pressure Monitoring 5000 1000 im"'CsgxTbg Annulus Pressure •■•04.Injection Pressure Inj Rate Incr due to Platform SD for 4500 - Injection Rate (bbl /d) DOT Pipeline Testing May 25 - 27th •W- Surface Casing Pressure 4000 800 a) L y 3500 a) • w oo 3000 60 . , c,) a) �tS 2500 � - - � �a f Cl) IT 1 = co 11 a L i A , a) 2000 I 400 a Q U 0) U I m 0) 1500 U) U 1000 200 • 500 0 ^- a""""a"" ilil"' l o 0 o� o� o o� o� o o� o� o� o� o� O O O O O O O O O O O O O O O O O O O O O O O O O O O O O O O O O O O O O O O O O O O S 0 A33 -14 Rate and Pressure Monitoring Surf Injected Casing Annulus Injection Comments [bbl] [psig] [psig] [psig] 7/1/2010 484 30 0 3,650 7/2/2010 480 30 0 3,650 7/3/2010 476 30 0 3,650 7/4/2010 501 30 0 3,650 7/5/2010 459 30 0 3,650 7/6/2010 442 30 0 3,550 7/7/2010 445 30 0 3,550 7/8/2010 456 32 0 3,625 7/9/2010 502 31 0 3,625 7/10/2010 496 32 0 3,625 7/11/2010 503 31 0 3,625 7/12/2010 494 31 0 3,625 7/13/2010 492 31 0 3,625 7/14/2010 477 32 0 3,625 7/15/2010 484 32 0 3,650 7/16/2010 473 33 0 3,650 7/17/2010 490 32 0 3,650 7/18/2010 494 32 0 3,650 7/19/2010 476 32 0 3,650 7/20/2010 481 32 0 3,650 7/21/2010 476 32 0 3,650 7/22/2010 500 32 0 3,650 7/23/2010 500 33 0 3,650 7/24/2010 494 32 0 3,650 7/25/2010 487 32 0 3,650 7/26/2010 493 32 0 3,650 7/27/2010 491 33 0 3,650 7/28/2010 494 33 0 3,650 7/29/2010 473 33 0 3,650 7/30/2010 438 33 0 3,650 7/31/2010 443 33 0 3,650 8/1/2010 464 33 0 3,650 8/2/2010 478 33 0 3,650 8/3/2010 454 33 3,500 3,650 8/4/2010 465 33 3,500 3,650 8/5/2010 475 36 3,550 3,650 annulus psi 8/6/2010 62 32 2,800 2,900 Bleed -off TCA Press & Re -Check 8/7/2010 0 30 2,750 2,800 annulus psi -SIW 8/8/2010 0 28 2,675 2,750 8/9/2010 0 28 2,650 2,750 8/10/2010 0 29 2,625 2,750 8/11/2010 0 28 2,600 2,625 8/12/2010 0 28 2,650 2,650 8/13/2010 0 28 2,250 2,550 8/14/2010 0 28 2,550 2,550 8/15/2010 0 27 2,250 2,250 8/16/2010 0 27 2,250 2,250 8/17/2010 0 27 2,600 2,250 8/18/2010 0 27 2,600 2,550 8/19/2010 0 28 2,600 2,555 8/20/2010 0 28 2,600 2,555 8/21/2010 0 28 2,600 2,555 8/22/2010 0 28 2,600 2,555 8/23/2010 0 28 2,600 2,555 8/24/2010 0 28 2,600 2,555 8/25/2010 0 28 2,600 2,555 8/26/2010 0 28 2,600 2,555 8/27/2010 0 28 2,600 2,555 8/28/2010 0 28 2,600 2,555 8/29/2010 0 28 2,600 2,555 8/30/2010 0 28 2,600 2,555 8/31/2010 0 28 2,600 2,555 • • Page 1 of 6 Maunder, Thomas E (DOA) From: Paul_Figel @xtoenergy.com Sent: Thursday, August 19, 2010 12:49 PM To: Maunder, Thomas E (DOA) Cc: Barney_Phillips @ xtoenergy.com; Cody_Mishler @xtoenergy.com; Greg_Duggin @xtoenergy.com; Regg, James B (DOA); Scott_Griffith @xtoenergy.com Subject: RE: Request for AA for MGS A33 -14 Tom, I'll let Greg Duggin give you the ETA on the equipment. And yes, we will have buy & install an auto SSV. Paul "Maunder, Thomas E (DOA)" To <tom.maunder @alaska.gov> Paul_Figel @xtoenergy.com cc Barney_Phillips @xtoenergy.com, Cody_Mishler @xtoenergy.com, Greg_Duggin @xtoenergy.com, "Regg, James B (DOA)" 08/19/2010 03:33 PM <jim.regg @alaska.gov >, Scott_Griffith @xtoenergy.com Subject RE: Request for AA for MGS A33 -14 A revision on AIO 9.007 will be necessary, but that should not be a major issue. I understand that Barney is responsible for the scheduling. Do you all have any estimate of when the equipment will be installed? If I have read your messages correctly, it will be necessary to install the safety valves as well or did I misread? Tom From: Paul_Figel @xtoenergy.com [mailto:Paul_Figel @xtoenergy.com] Sent: Thursday, August 19, 2010 11:59 AM To: Maunder, Thomas E (DOA) Cc: Barney_Phillips @xtoenergy.com; Cody_Mishler @xtoenergy.com; Greg_Duggin @xtoenergy.com; Regg, James B (DOA); Scott_Griffith @xtoenergy.com Subject: RE: Request for AA for MGS A33 -14 Barney Phillips is assigned to all SSV & SSSV testing and maintenance. We will put these on the 6 month schedule. Will I have a new number for AA or use the same number as on the C24 -23 - "AIO 9.007" when we get the equipment installed? Thanks for working with us. Paul "Maunder, Thomas E (DOA)" 2/18/2011 • Page 2 of 6 <tom.mau n der @alaska.gov> To Paul_Figel @xtoenergy.com 08/19/2010 02:25 PM cc Barney_Phillips @xtoenergy.com, Cody_Mishler @xtoenergy.com, Greg_Duggin @xtoenergy.com, Scott_Griffith @xtoenergy.com, "Regg, James B (DOA)" <jim.regg @alaska.gov> Subject RE: Request for AA for MGS A33 -14 Paul, et al, Jim Regg and I have examined your proposal and we believe it is the appropriate way to provide an additional safety level for wells (A33 -14 and C24 -23) that have developed T x IA communication. What sort of installation schedule to you anticipate? The standard practice for similar installations on the NS is that the pilot and valve are tested every 6 months with the normal safety valve testing. Thanks to all for your quick attention to this matter. Tom Maunder, PE AOGCC From: Paul_Figel @xtoenergy.com [ mailto :Paul_Figel @xtoenergy.com] Sent: Thursday, August 19, 2010 11:04 AM To: Maunder, Thomas E (DOA) Cc: Barney_Phillips @xtoenergy.com; Cody_Mishler @xtoenergy.com; Greg_Duggin @xtoenergy.com; Scott_Griffith @xtoenergy.com Subject: RE: Request for AA for MGS A33 -14 Tom, An Axelson pressure sensor (see attached) will be on the 7" x 10.75" annulus, which in turn will be connected to an auto surface safety valve (SSV) that will be installed on the injection tbg at the wellhead. When this sensor is triggered, the SSV will automatically close. Talking to Greg Duggin, with this in place, there would not be a need for a pop -off valve. We would bleed -off the tbg & IA pressure after having communication. Attached is a graph of the bleed -off pressure when the A33 -14 was SI on Aug 4th. Paul "Maunder, Thomas E (DOA)" <tom.mau nder @alaska.gov> 08/19/2010 12:43 PM To Paul_Figel @xtoenergy.com cc Scott_Griffith @xtoenergy.com, Greg_Duggin @xtoenergy.com, Cody_Mishler @xtoenergy.com, Barney_Phillips @ xtoenergy.com Subject RE: Request for AA for MGS A33 -14 2/18/2011 Page 3 of 6 Paul, Sorry I did not get back to you yesterday. Were would the pop -off relieve to? If communication did develop, shutdown would need to be pretty quick. How does the pressure fall off when these wells are SI? It might be necessary to bleed off the tubing /IA pressure to avoid overpressure in the OA. Tom From: Paul_Figel @xtoenergy.com [mailto:Paul_Figel @xtoenergy.com] Sent: Thursday, August 19, 2010 7:15 AM To: Maunder, Thomas E (DOA) Cc: Scott_Griffith @xtoenergy.com; Greg_Duggin @xtoenergy.com; Cody_Mishler @xtoenergy.com; Barney_Phillips @xtoenergy.com Subject: RE: Request for AA for MGS A33 -14 Tom, I left you a voice mail yesterday about installing a pressure relief valve on the 7" x 10 -3/4" that would tie into our production header. We could set the pop -off at ± 500 psi (well below burst & frac press of the shoe). If the press communicated from the production csg to the surface, the pop -off would open & then we would shut -in the well until the well was repaired by workover. We would also put a pop -off on the C24 -23. Therefore, along with the pop -off valve and injection rate monitoring for abnormal increases, we should know if we are keeping the injection in zone. Let me know if this would be ok. Thanks, Paul Paul Figel Engineering Manager XTO Energy Inc. Midland, TX 2/18/2011 • Page 4 of 6 Office: 432- 620 -6743 Cell: 432- 553 -5217 Fax: 432 -687 -0862 "Maunder, Thomas E (DOA)" <tom.maunder @alaska.gov> 08/13/2010 05:11 PM To Paul_Figel @xtoenergy.corn cc Subject RE: Request for AA for MGS A33 -14 Paul, I am looking at your request for administrative approval. For approvals with T x IA communication we look at the ratio of the injection pressure to the burst ratings of the production and surface casings. That ratio for the production casing is pretty critical since the IA is pressured up due to the communication. The ratio for the surface casing is important when failure of the production casing is concerned. For A- 33 -14, I calculate the following ratios based on the steady wellhead pressure submitted with the application. Production casing: 7 ", 23 #, N -80 at surface -- ratio = 3650 / 6340 = 57% Surface casing: 10 -3/4" 40.5 #, J -55 -- ratio = 3650 / 3130 = 117% I looked back at C -24 -23 (AIO 9.007) and the ratios are Production casing: 7 ", 26 #, N -80 at surface -- ratio = 3500 / 7240 = 48% Surface casing: 10 -3/4" 40.5 #, J -55 -- ratio = 3500 / 3130 = 111% I do not know if these calculations were made when AIO 9.007 was approved. There are other approvals out there (in other fields) where the production casing pressure ratio is about 60 %, however I am not aware of any wells with approvals where the surface casing ratio exceeds 2/18/2011 Page 5 of 6 100% of published burst. The recent practice, where repair /workover is not planned and the production pressure ratio is around 60 %, is to require a pressure pilot be installed on the outer annulus with the intent to halt injection should the pressure threshold be exceeded. Please get back to me as soon as you can regarding the pressure situation on both wells. Tom Maunder, PE AOGCC Original Message From: PaulFigel @xtoenergy.com [ mailto :Paul_Figel @xtoenergy.com] Sent: Friday, August 13, 2010 9:04 AM To: Maunder, Thomas E (DOA) Subject: RE: Request for AA for MGS A33 -14 Thanks, Tom. Paul Figel Engineering Manager XTO Energy Inc. Midland, TX Office: 432 - 620 -6743 Cell: 432 - 553 -5217 Fax: 432 - 687 -0862 "Maunder, Thomas E (DOA)" <tom.maunder @alas To ka.gov> PaulFigel @xtoenergy.com cc 08/13/2010 08:05 Scott Griffith @xtoenergy.com, AM Scott Landon @xtoenergy.com, Greg Duggin @xtoenergy.com Subject RE: Request for AA for MGS A33 -14 Paul, et al, I believe I can handle this with your electronic application. Tom maunder, PE 2/18/2011 Page 6 of 6 411 411 AOGCC Original Message From: Paul_Figel @xtoenergy.com [ mailto :Paul_Figel @xtoenergy.com] Sent: Thursday, August 12, 2010 11:55 AM To: Maunder, Thomas E (DOA) Cc: Scott_Griffith@xtoenergy.com; Scott @xtoenergy.com; Greg_Duggin @xtoenergy.com Subject: Request for AA for MGS A33 -14 Tom, Can you please submit this request electronically or let me know if I need to send in hard copies through the mail. I'm still on Platform A watching the paint dry. Thanks, Paul (See attached file: AOGCC Letter for AA A33 -14 to Cont Inj.doc)(See attached file: A33-14 Rate and Pressure Monitorin g 2010.xls AUG )( See attached file: A33 -14 Inj Plot.pdf)(See attached file: A33 -14 WIW Current WBD 10- 27- 00.doc) Paul Figel Engineering Manager XTO Energy Inc. Midland, TX Office: 432 - 620 -6743 Cell: 432 - 553 -5217 Fax: 432 - 687 -0862 2/18/2011 • ft GY XTO Energy Inc. 200 North Loraine Suite 800 Midland, Texas 79701 432 - 682 -8873 432 - 687 -0862 (Fax) August 12, 2010 Alaska Oil and Gas Conservation Commission Attn: Mr. John Norman 333 West 7th Ave., Suite 100 Anchorage, Alaska 99501 RE: Request Administration A royal to Continue Water Injection for MGS A33 14 Cook Inlet, e uest q pp Injection > AK. Dear Mr. Norman: XTO Energy Inc. is seeking approval to allow the continued water injection for MGS well #A33 -14 located on Platform A, in Cook Inlet. This well was has been on injection since 1969 and provides water - flood support to producers in the East Flank Hemlock. On August 6, 2010, the well experienced pressure communication between the injection tubing and the 5" casing and was shut -in. Prior to this date, the well has been injecting water at an average of 470 BWIPD @ 3600 psi WHP for the past 5 years. (Please see attached plots.) It is not known if the pressure communication is residing within the packer or the tubing and would like to continue injection while monitoring the WHP, tubing- casing annulus pressure, surface casing pressure and water injection rate. The well would be shut -in immediately if the injection rate increases above the normal operating range. If you require additional information, please contact me with any questions @ 432 - 620 -6743. Sincerely, Paul L. Figel Engineering Manager Cc: Scott Griffith Scott Landon Attachments: A33 -14 Inj Plot — History 1969 - Present A33 -14 Rate & Pressure Data 1 year A33 -14 Wellbore Diagram axelson ESP pressure sensor • • Page 1 of 2 f Imp PC McKenzie McKenzie Company 877-244-4883 HOME_ ...Site Map :•Contact Us ��u5S�1 S t� °1- ` Boiler Sales Axelson ESP Pressure Sensor C u Boiler Parts The Axelson ESP Pressure Sensor is a highly accurate and reliable device designed to detect an abnormal operating condition in a Kewanee Boiler Parts safety system and transmitting a signal to perform a specific shutdown function. ' r ' t Cng Compressors The Axelson ESP Pressure Sensor is a 3 -way block and bleed valve Cng Compressor Parts that is controlled by a piston and spring. 11 Cng Conversion It is used to sense predetermined pressure and, when that pressure is reached, shift the 3 -way valve. Electric Vehicle Charging " Axelson Relief Valves The actuation point is easy to adjust by turning the adjustment cap. This changes the spring force. Turning the cap clockwise will increase Axelson Spare Parts the pressure setting. Turning the cap counter clockwise will decrease Axelson Applications the pressure setting. Axelson ESP Pilot The sensor may be used to detect high pressure or a low- pressure condition by connecting Axelson Orifice the input instrument pressure to the appropriate port. When connected to either port the remaining port becomes the exhaust port. Axelson Pressure Sensor When used in a high pressure sensing application, the sensor allows flow through the Axelson CRBBM Relay instrument ports from "low" input to output as long as the sensing pressure increases to the Axelson Teststand high set point, the instrument input is blocked and the output is bled to the exhaust port. Relief Valve Maintenance When used in a low pressure sensing application, the sensor allows flow through the Advantage of Axelson instrument ports from "low" input to output as long as the sensed pressure is above the low set pressure. When the sensing pressure decreases to the low set point, the instrument is Garrett Safety Valve blocked and the outlet is bled to the exhaust port. Amot Valves FEATURES: • Sensing pressure range from .5 to 20,000 psi • Instrument pressure range up to 200 psi • Block- and -bleed 3 -way valve • Designed for 3% repeatability of set point, or 5 psi, whichever is greater. • Minimum spread (dead band) between trip and reset pressure • Spring maybe be replaced with instrument and sensing pressures present • Vent in lower housing provides warning if body is accidentally loosened from lower housing with sensing pressure present • Available to conform to NACE Standard MR -01 -75 • Corrosion resistant 316 stainless steel used throughout with Inconel spring optional. • Sensing pressure connections: 9/16" HP on high - pressure sensors (20,000 psi) Y < <" NPT on low pressure sensors (diaphragm type) W NPT on all other sensors http: / /www.mckenziecorp .corn /axelson_sensor.htm 8/10/2010 Axelson CRBBM Relay • • Page 1 of 2 AMID AWL P.C. McKenzie Company 877.244 -4883 Boiler Sales Axelson CRBBM Relay Boiler Parts OPERATION: With control (actuator) supply Marxist Hardie connected to the supply pressure inlet and no Kewanee Boiler Parts instrument pressure at pilot pressure inlet, control a■ pressure is blocked at the supply pressure inlet and ` . l Cng Compressors the supply pressure outlet is open to the exhaust ports pressure 'Vi�� B ody (rad holes in body). When instrument pressure is Outlet , 'l7`` ----1 Cng Compressor Parts applied to the pilot pressure inlet of the relay, it acts , 11 \ Revue against the relay piston, shifting it to an open position. ')r Inlet 1 \. Cng Conversion This allows control pressure to pass from the supply 1\ ® ' ® pressure inlet through supply pressure outlet to open `� ExhaustParls Axelson Relief Valves the SSV safety valve. It will remain in the position Vorlt until instrument pressure is bled from the pilot t IF ® � �sros "' Axelson Spare Parts pressure inlet. Once the PSHL blocks and bleeds `i � <ii wel oi Axelson Applications pressure from the pilot pressure inlet, the relay spring krL '. Axelson ESP Pilot will f the relay piston downward to its block and -{J. ► ►►` i Mewl Loc bleed position, blocking control pressure at the supply v .-_ Y Axelson Orifice pressure inlet and opening the supply �.—r "" p p g pp y pressure outlet e Y to exhaust, allowing the SSV safety valve to close. ; WWI Pressure Sensor r a Axelson CRBBM Relay The CRBBM Relay will remain closed until instrument trot Prime Inlet supply is readmitted to the pilot pressure inlet. Once t" , C Axelson Teststand instrument pressure is readmitted to the pilot pressure ' 1 , o ©'� C- ` � Relief Valve Maintenance inlet, the relay will shift automatically to its open 5 c. V G V L Advantage of Axelson position. v t C.C. e- Garrett Safety Valve TECHNICAL DATA: DESIGN OVERVIEW: Maximum Working Pressure: 250 psi The relay is normally- closed fast block and Amot Valves Pilot Pressure: 35 to 150 psi* bleed valve which may be manually operated Length: 71/4 in. or be programmed to automatically resent or Connections: 1/4 NPT to require manual rest and provide a means Weight: 2 3/4 lbs. to manually override the safety system. Material: All corrosion resistant Applications of pilot pressure allows supply pressure to pass from inlet port to outlet port. When the the pilot pressure is removed, the relay shuts off the supply pressure and back bleeds quickly. TYPICAL APPLICATION FOR CRBBM RELAY APPLICATION: The figure to the right illustrates a typical application for the relay. In this application, the 20 5 PS relay is utilized to separate the higher control pressure PSI from the lower pressure instrument supply and to PSHL "CRBBM" Relay provide a means of fast bleeding the SSV Safety valve Sensor f ■ actuator pressure which is not possible through the ■ smaller orifices of the PSHL sensor. It provides the '�' means to manually override the PSHL sensor to hut in "' ' and lock out the system once the SSV safety valve is closed. Flow SSV Safely Valve CONTACT INFO: OR GO TO OUR CONTACT PAGE AND CHAT LIVE MAILING: PHONE: SHIPPING: P.C. McKenzie Company 1- 877 - 244 -4883 P.C. McKenzie Company P.O. Box 112638 Fax: 412- 257 -8890 1365 McLaughlin Run Road Pittsburgh, PA 15241 Phone: 412 - 257 -8866 Pittsburgh, PA 15241 http: / /www.mckenziecorp.com /axelson- crbbm - relay.htm 8/10 /2010 XTO Energy - A33 -14 Rate and Pressure Monitoring 5,000 1,000 CsgxTbg Annulus Pressure 4,500 Injection Pressure 900 ,., Injection Rate (bbl /d) Surface Casing Pressure 2 4,000 800 y z co ca a ♦ 3,500 - 700 p • c E' O V 3,000 600 c o pd i • 2,500 500 N -5 L c a c < 2,000 400 c N .G to I— U x N 1,500 300 v U t 1,000 200 • 500 100 AA : . : I I I- 1 0 ^ �O �O e ?. �O �O �O .O w1, � n O ^ ^ O t. O ^O ^ ^ O O O O O O O PSI A33-14 !NJ HEMLOCK Hrs On 3,750 - -30 3,500 - -28 3,250 - -26 3,000 -24 2,750 - -22 2,500 - -20 2,250 - 1E, 2,000 -18 1,750 - -14 1,500 - -12 1,250 - -10 1,888 - -8 750 - -6 500 -4 250 - -2 0 - - - - - - - - - - - - - r - - - - - - - - - - r - - 4 0 7/19/10 8/1 8/15 8/18/10 — Casing Pressure . -. Tubing Pressure — Annulus Pressure -- urface asingPressure - -- Inte MGS A33 -14 (INJ) HEMLOCK 10000 _RIEN ∎mil■ L ' ■� , .- • EMI , , , I 1 ' I %.� NN ! I� I I 11 1 I NNNNN II 1 ,, 1 , 1 prrilirtul gm i I pi,,,,,,A,...., . 1000 c �� i �� � riiiiuiuilluIIiu a��� . _ __ mm it i as ■ l Il _ 'mi�__m o■■��Tmust mil i .. �� NW IL .. 21 MN =� ��mA MOM M���w�= �� IY N NN irr t Ni T T • N • ■ 1NN ■NNE i iitiNN�Nr 0161d a�' :, • • a. co 1 I ' 1 100 ' I I 1 ■■1■r..— re_ ,- .......... - - - -a I 1 mom mow m! fir— 1 __ IIIIIIII l 1 ■ 1 , NN H IN_ N �I - 1 - - -- -1 I I � .__ 1 I I ! I l I I � I 10 - • I r l � _4 , -I- I I f ( I N 1 I ! i ■i CD WtrInj MGS A33 -14 (INJ) ! 1 196970 71 72 73 74 75 76 77 78 79 80 81 82 83 84 85 86 87 88 89 90 91 92 93 94 95 96 97 98 9200 6D1 02 03 04 05 06 07 08 09 10 Date MGS A33 -14 (INJ) HEMLOCK 10000 _ , I ) — — f , - 1 � 1 F � 1 r M� ,fit.... _ ■ , i i 1000 — == t • L • IIr I _ T -iii■■ ii r ;t �."Vri ME • IN 11111A1 f • ■■ 1 V • _ ■■ O � _- § III • 111111111 CO IIIIIIII III • II 1 100 - N•• IP ; ♦ 1 NI 1 1111 ■ _■_ 1 _ N ■E 1 - I El I i — A33 -14 (INJ) 1 -+�-*- CD Wtrinj MGS ( ) 1 1 ,j, . ;, , - ,, ,' i i i i i i i I I i � i � i �Ti � I I I i i rte - - - i � i i r i i i I i i i i'i' 1969'0 71 72 73 74 75 76 77 78 79 80 81 82 83 84 85 86 87 88 89 90 91 92 93 94 95 96 97 98 9200 0D1 02 03 04 05 06 07 08 09 10 Date • . ) 5f'O cdp 10/27/2000 ENERGY Present Completion MGS A33 -14 WIW Cook Inlet, Alaska Leg 4, Conductor 30 API No.: 7/21/2000 Tbg: Spud: 2 3/8" 4.7# N80 8R EUE ABMOD 1" X @ 329' 1.875 X nipple nipple @ 9576' Surf Csg: 10 3/4 ", 40.5 Ib., J55. Bkr DB pkr @ 9610' Set © 1871'. Cmt'd w/ 1975 sx. 1.875" X nipple @ 9632' 1.791" XN nipple @ 9641' WL re -entry guide © 9648' EOT @ 9649' 44444 `•••88 1984 Csg leak @ 6150'. Sqz'd w/ 200 sx G (5/ ••. , % 44**: . 41 . .1 . 4! . .. : 1 + ❖ ee4 22/84, then ran 5" liner to isolate old perfs). 444.444 woe:" ■ v 0 1 1° 0 rd Prod Csg: 7 ", 23 #, N80 Buttress. Set @ 0 -6500' 7 ", 26 #, N80. Set @ 6500'- 9900'. 7 ", 29#, N80. Set @ 9900'- 10531' Cmt'd w/ 1100 sx. PZ 0, ►' 7/13/00 Cut 7" csg @ 88'. Ran OS, 7" x - - -- 46.2# and install new wellhead and K GN - GO: 9061 - 9085 (Behind Liner) I= stainless tree. • GR -GS: 9435 -9451 (Behind Liner) • ,rr ► GR -GS: 9456 -9472 (Behind Liner) Cil .' HC-HD: 9715' -9804' Liner 5/28/84: 5 ", 18 Ib N80 A ... HE -HF: 9860 -9888 (Behind Liner) SFJP. Set @ 8956'-10432'. Cmt :� HI -HK: 9954 -9995 (Behind Liner) w/ 150 sx G. Circ out excess. No 'ig HK -HN: 10060'- 10162' Po pipe movement while cmt. . HN -HR: 10162'- 10239' `y: 4 HN -HR: 10260'- 10302' 7/15/2000 Ran liner to Surface: a :. HR -HZ: 10328'- 10419' 5" 18# N80 Hydril 513 from 8950' ►`� to surface. Cmt to surface w/ 132 A , bbl G (15.8 ppg). AO 61 N S' PBTD: 10432' 5/21/84 original perfs sqz'd w/ 250 sx G below cmt TD: 10555' retainer @ 9593' ~~ Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Wednesday, August 11, 2010 8:43 AM To: 'Paul_Figel@xtoenergy.com' Cc: 'Scott Griffith c~jctoenergy.com ; 'Cody_Mishler@xtoenergy.com ; 'Kyle_Hammond@xtoenergy.com' Subject: RE: Press communication on A33-14 (167-068) WIW Paul, I received the latest monitoring information for C24-23. Do you have similar information for A33-14? Since it appears based on our conversation that you will be making an Administrative Approval application and such informat,on,wll...~e..paxt of the AA that it is appropriate to start sending in the pressure/rate data. Call or message with any questions. Tom Maunder, PE AOGCC -----Original Message----- From: Maunder, Thomas E (DOA) ~,, ~ ,~~,:; - _ ~'~~ ~I,; y. .,. ~(~ Sent: Friday, August 06, 2010 9:54 AM To: 'Paul Figel@xtoenergy.com' Cc: Scott Griffith@xtoenergy.com; Cody_Mishler@xtoenergy.com; Kyle_Hammond@xtoenergy.com Subject: RE: Press communication on A33-14 (167-068) WIW Hi Paul, An AA would be the appropriate way to proceed. Call when you have a chance. Tom Maunder, PE AOGCC -----Original Message----- From: Paul_Figel@xtoenergy.com [mailto:Paul_Figel@xtoenergy.com] Sent: Friday, August 06, 2010 9:46 AM To: Maunder, Thomas E (DOA) Cc: Scott_Griffith@xtoenergy.com; Cody_Mishler@xtoenergy.com; Kyle_Hammond@xtoenergy.com Subject: Press communication on A33-14 WIW Tom, We have a water injector on Platform A, A33-14, that is an East Flank injector that started communicating press to the tbg annulus on Tues with WHP @ 3650 psi & the tbg ann @ 3500 psi @ 454 BWIPD. The day prior was 0 psi on the tbg ann. We stopped inj & bled-off the press on Wed, then put it back on to see if the press came back, in which it did. Therefore, as of last night, the well has been SI. I would like to pursue getting approval from the state similar to the C24-23 with a AI09.007 that we continue to monitor the injection rate and both pressures that would indicate that the injection is still staying within zone & not increasing in volume that would suggest we are injecting uphole. How would you like me to proceed? I am on Platform A overseeing the 3 coil tbg workovers this week & can reached on my cell phone (432-553-5217) or "A" 907-776-2500 if you need to call me. Thanks, Paul (See attached file: A33-14 WIW Current WBD 10-27-OO.doc} Paul Figel Engineering Manager XTO Energy Inc. Midland, TX 1 • MEMORANDUM TO: Jim Regg ~ j~z? 1~;;;; ~~, P.I. Supervisor FRONT: Lou Grimaldi Petroleum Inspector State of Alaska Alaska OiI and Gas Conservation Commission DATE: Tuesday, May 27, 2008 SUBJECT: Mechanical Intep~ityTests XTO ENERGY INC A33-14 MGS A33-14 Src: Inspector NON-CONFIDENTIAL Reviewed By: P.1. Suprv ~ f~-. Comm Well Name: MGS A33-t4 API Well Number: s0-733-200s7-00-00 Inspector Name: Lou Grimaldi Insp Num: mitLG080s 18093518 Permit Number: 167-068-0 ~ Inspection Date: S!I Sr2008 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well; A33 to-jType Inj. ~' I~ TVD~~~ ! 79az~I o zzzo .~ zzzo '~, zzzo P.T. 'i t6~o6ao TypeTest sPT !Test psi ' 22zo ~'pA to ~s is ~s I~ -- - --- - -- Interval aYRrsr PIF - P -_ _- -------- Tubing- - - - - - - -_. ------ 360 36s0 ' 360 36s0 Notes: Good Test. ~~~~C~ MAC ~ $ 200 Tuesday, May 27, 2008 Page 1 or 1 .'-'-" ~" MEM 0 RAND UM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg P.I. Supervisor 'Qe{(q &11\ LYr DATE: Wednesday, June 02, 2004 SUBJECT: Mechanical Integrity Tests XTO ENERGYINC A33-]4 MGS A33-14 1£7 -ö~c¿ FROM: JeffJones Petroleum Inspector Src: Inspector Reviewed By: P.I. Suprv 5ß.ç-... Comm NON-CONFIDENTIAL Well Name: MGS A33-14 API Well Numbe Permit Number 50-733-20057-00-00 Inspector Name: 1670680 Inspection Date: Jeff Jones 5/10/2004 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well: I A33-l4 Type Inj. s TVD 8804 IA 60 2240 2240 2240 P.T. ]670680 TypeTest SPT Test psi ]995.5 OA 30 30 30 30 Interval 4YRTST P/F p Tubing 3700 3700 3700 3700 Notes: Pre-test pressures monitored & stable. Standard annulus pressure test performed, well passed MIT & is suitable for continued injection. Wednesday, June 02, 2004 Page] of] WATER INJECTION REPORT PLATFORM A Novemlgr-2002 DATE & NOTES 01-Nov-2002 02-Nov-2002 03-Nov-2002 04-Nov-2002 05-Nov-2002 06-Nov-2002 07 -Nov-2002 0g-Nov-2002 09-Nov-2002 I 0-Nov-2002 11 -Nov-2002 12-Nov-2002 13-Nov-2002 14-NOV-2002 15-Nov-2002 16-Nov-2002 17-Nov-2002 IS-Nov-2002 19-Nov-2002 20-Nov-2002 21 -Nov-2002 22-Nov-2~02 23-Nov-2002 24-NOV-2002 25-Nov-2002 26-Nov-2002 27-Nov-2002 2g-Nov-2002 29-Nov-2002 30-Nov-2002 TOTAL MAXIMUM AVERAGE # DAYS A33-11LS ;C~3 INJ ANNU 976 3600 50 983 3700 50 975 3700 50 968 3575 50 970 3600 50 965 3600 50 963 3600 50 957 3600 50 832 3600 50 A41A-11LN INJ INJ ANNL 597 3600 612 3600 606 3600 603 3700 600 3700 587 3650 589 3650 600 3650 592 3650 604 3650 550 3650 DISPOSAL WELL A44-11 INJ INJ ANNU 0 100 6~ 0 100 0 100 6( 0 100 6( 0 100 0 100 6( 0 90 6( 0 100 0 100 6( 0 100 0 100 6( AII-13R2 INJ l~J ANNU 288 3600 18.~ 297 3600 316 3600 344 3700 179 3700 18: 246 3650 18: 242 3650 9( 255 3650 9( 274 3650 9( 286 3650 229 3650 AIl-12 J 546 3600 250 240 3100 300 609 3100 300 592 3650 300 595 3650 225 593 3650 220 589 3650 225 590 3650 225 504 3650 210 A33-14 J A44-02 ACT ACT 550 3600 10( 773 3600 591 3700 7~ 784 3700 572 3700 7~ 773 3700 606 3650 7f 773 3650 609 3650 5~ 769 3650 606 3650 5( 763 3650 601 3650 6( 764 3650 608 3650 5( 759 3650 511 3650 5( 656 3650 932 3600 45 926 3575 918 3550 5C 920 2575 5C 914 36OO 45 981 3650 4( 952 3650 4~ 935 3650 4( 927 365O 4( 941 3625 45 943 3625 924 3625 4~ 934 3625 45 934 3625 45 942 3625 922 3625 4.' 938 3625 8~ 907 3625 910 3625 4( 28,299 3,700 8.~ 943 3,584 4g 3O 605 3650 597 3650 594 3650 607 3650 610 3650 648 3700 641 3700 634 3700 618 3700 622 3700 633 3700 617 3700 613 3700 631 3700 635 3700 609 3700 630 3700 620 3700 602 3700 18,306 3,700 610 3,672 3O 0 100 0 100 0 5O 0 50 0 50 0 50 0 50 0 50 6( 0 50 0 100 50 0 100 50 0 100 50 0 I00 50 0 100 50 0 100 50 0 100 50 0 100 50 0 50 50 0 50 50 0 100 60 0 85 57 163 3650 90 594 3650 210 182 3650 90 593 3650 225 210 3650 170 591 3625 225 212 3650 150 596 3650 200 208 3650 150 591 3650 225 277 3650 150 705 3700 175 266 3700 150 683 3700 150 263 3700 150 670 3700 150 273 3700 150 651 3700 150 269 3700 145 657 3700 175 283 3700 150 659 3700 175 288 3700 150 641 3700 175 284 3700 145 642 3700 175 296 3700 145 647 3700 175 296 3700 145 653 3700 175 277 3700 145 630 3700 175 286 3700 145 634 3700 175 265 3700 14~ 605 3700 150 258 3700 14~ 592 3700 15C 7,812 3,700 185 260 3,670 142 3O 17,941 3,700 30~ 598 3,631 206 3O 571 3650 561 3650 564 3650 576 3650 571 3650 762 3700 709 3750 689 3750 655 3750 668 3700 671 3700 648 3700 651 3700 667 3700 673 3700 638 3700 640 3700 598 3700 582 3700 18,374 3,750 612 3,677 3O 5( 748 3650 5: 752 3650 5! 743 3650 5( 741 3650 5( 734 3650 ~ 776 3700 ~ 758 3700 )[ 748 3700 )i 737 3700 ii 747 3700 ff 747 3700 25i 732 3700 25: 740 3700 251 732 3700 25 735 3700 25 728 3700 0 735 3700 25 707 3700 25 709 3700 22,431 150 3,700 43 748 3,672 30 12/12/2002 WATER INJECTION REPORT PLATFORM A DISPOSAL WELL October-2002 A33-1 ILS A41A-I ILN A44-I I A11-13R.2 Al 1-12 A33-14 A44-02 DATE & NOTES INJ INJ 01.Oct-2002 961 3575 140 559 3625 0 0 100 75 380 3625 131 550 3650 36~ 557 3650 20(} 709 3650 90 02.Oct-2002 965 3575 130 559 3625 0 0 100 70 364 3625 131 550 3650 35£ 554 3650 19~ 719 3650 80 03-Oct-2002 959 3575 130 552 3625 0 0 100 70 375 3625 13¢ 550 3650 35C 557 3650 19~ 707 3650 80 04-Oct-2002 963 3575 130 555 3625 0 0 100 70 386 3625 131 558 3650 35£ 571 3650 19~ 716 3650 80 05-Oct-2002 1021 3575 100 598 3625 0 0 100 70 446 3625 111 650 3650 32£ 741 3650 16~ 773 3650 80 06-Oct-2002 831 3575 80 516 3625 0 0 100 70 367 3625 101 537 3650 30( 589 3650 160 623 3650 60 07.Oct-2002 930 3575 50 537 3625 0 0 100 70 265 3625 14~ 561 3650 26~ 655 3650 50 703 3650 08-Oct-2002 959 3575 50 569 3625 0 0 100 70 272 3625 171 572 3650 275 669 3650 60 707 3650 09-Oet-2002 1014 3575 50 594 3625 0 0 100 70 345 3625 171 652 3650 25£ 710 3650 60 774 3650 10-Oct-2002 979 3625 100 579 3650 0 0 100 65: 342 3650 12: 607 3650 26~ 612 3650 40 745 3650 1 l-Oct-2002 971 3625 65 605 3650 0 0 100 70 341 3650 12: 598 3650 26~ 610 3650 40 738 3650 12-Oet-2002 979 3625 65610 3650 0 0 100 651349 3650 12.~ 604 3650 26~ 618 3650 100 739 3650 13-Oct-2002 955 3625 65 570 3650 0 0 100 60 332 3650 131 586 3650 271~ 589 3650 100 722 3650 14-Oct-2002 958 3625 65 562 3650 0 0 100 60 313 3650 13: 586 3650 275 591 3650 110 718 3650 15-Oct-2002 952 3625 65 571 3650 0 0 100 60 320 3650 13.' 583 3650 275 593 3650 110 705 3650 16-Oet-2002 974 3625 55 606 3650 0 0 100 65i 343 3650 12.' 601 3650 .25C 615 3650 90 734 3650 17.0ct-2002 960 3600 60 572 3650 0 0 100 6( 343 3650 12: 587 3650 25C 595 3700 97 723 3700 18-Oct-2002 958 3600 50 598 3650 0 0 50 6( 355 3650 12( 593 3675 25C 612 3700 97 716 3650 19-Oct-2002 956 3600 50585 3650 0 0 50 6( 351 3600 111585 3650 25C 594 3700 90 712 3650 20-Oct-2002 951 3600 55 564 3650 0 0 50 6( 345 3600 121 581 3650 250 587 3700 90 706 3650 21.Oct-2002 598 3600 60 350 3650 0 0 50 6( 213 3650 121 369 3650 250 373 3700 99 448 3700 22-Oct-2002 0 3600 60 0 3650 0 0 50 6( 0 3650 121 0 3650 250 0 3700 99 0 3700 23-Oct.2002 0 2050 60 0 1000 0 0 50 6( 0 950 12( 0 2850 250 0 3100 99 0 2200 24-Oct-2002 29 1900 440 16 950 0 0 100 6( 3 950 29( 7 2850 60~ 8 3000 600 11 2150 47( 25-Oct-2002 326 1800 380 240 1950 0 0 100 6( 7 1850 30( 74 2850 550 107 3025 525 119 2100 38( 26-Oct-2002 700 1700 295 336 950 0 0 100 6( 106 850 30.~ 237 2800 60~ 9 2950 600 309 , - 1950 49( 27-Oet-2002 1430 3600 20 779 3650 0 0 100 7( 227 3650 191 693 3650 175 656 3650 0 1093 :, 3650 28-Oct-2002 1225 3625 25 723 3700 0 0 100 7( 270 3700 17{ 724 3700 150 793 3700 0 961 3700 29-Oct-2002 1046 3600 40 649 3650 0 0 100 6( 267 3650 15.~ 587 3650 175 595 3650 0 824 3650 30-Oet-2002 1045 3475 50 614 36~0 0 0 100 6( 197 3600 18.' 501 3600 250 463 3600 150 827 3600 31-Oct-2002 1010 3600 50 605 3600 0 0 100 6( 271 3600 18.~ 522 3600 250 503 3600 150 808 3600 TOTAL 26,605 15,773 0 8,495 15,405 15,726 19,789 MAXIMUM 3,625 440 3,700 0 100 7.~ 3,700 305 3,700 600 3,700 600~ 3,700 49~ AVERAGE 858 3,371 98 509 3,327 0 0 90 65 274 3,315 15~ 497 3,544 296 507 3,577 147 638 3,453 58 # DAYS 29 29 0 29 29 29 29 11112/2002 ,SCANNED NAR 1 0 2003 WATER INJECTION REPORT PLATFORM A DISPOSAL WELL September-2002 A33-1 ILS A41A-I ILN A44-11 Al 1-13R2 A1 I- 12 A33-14 A44-02 DATE & NOTES INJ INJ ANNU INJ INJ INS INJ ANNU INJ INJ ANNU INJ INJ ANNU INJ 13IJ ANNU INJ INJ 0 l-Sep-2002 981 3625 265 610 3600 0 0 100 80 429 3625 12.~607 3650 400 620 3650 20C 722 3650 120 02~$ep-2002 948 3625 285 605 3600 0 0 100 80 397 3625 13( 546 3650 40~ 523 3650 25( 693 3650 140 03-$ep-2002 966 3625 275 608 3600 0 0 I00 80397 3625 13.'555 3650 4013 543 3650 2512703 3650 140 IM-$¢p-2002 952 3625 275 605 3600 0 0 100 80388 3625 141 544 3650 40(] 532 3650 25(2698 3650 130 05-$¢p-2002 870 3625 275 543 3600 0 0 100 80 308 3625 14( 446 3650 40t3 444 3650 25£ 585 3650 130 06-Sep-2002 1025 3625 275 596 3600 0 0 100 80 341 3625 140 561 3650 4012 583 3650 25£ 755 3650 131] 07-5ep-2002 610 3625 25(] 608 3600 0 0 I00 80 343 3625 150 539 3650 40C 540 3650 22£ 715 3650 121] 05-S¢p-2002 1116 3625 2013 583 3600 0 0 100 813 351 3625 150 540 3650 38C 543 3650 22( 719 3650 1213 09-$¢p-2002 995 3625 215 594 3600 0 0 100 8(]352 3625 150 540 3650 40( 540 3650 22( 715 3650 1413 10-5¢p-2002 983 3625 215 598 3600 0 0 100 8(] 357 3625 150 543 3650 4OC 544 3650 22( 711 3650 14~ 11-5¢p-2002 958 3625 215 586 3600 0 0 I133 8(] 354 3625 150 535 3650 40( 537 3650 22( 705 3650 1412 12-8ep-2002 973 3600 21¢ 574 3650 (] 0 I00 8(3 349 3650 145 559 3650 39( 595 3650 22: 715 3650 13-5ep-2002 975 3600 2112 584 3650 13 0 100 8(2 338 3650 145 561 3650 37~' 565 3650 22( 717 3650 913 14-5ep-2002 957 3600 2112 573 3650 (] 0 100 8(2 334 3650 145 541 3625 375 541 3650 211 707 3650 15-Sep-2002 1015 3600 18£585 3650 (] 0 100 8C379 3650 130 627 3625 35( 703 3650 151 746 3650 10C 16-Sep-2002 958 3625 151 579 3650 1~ 0 100 8(2357 3625 125 560 3650 37.~ 558 3650 17.'711 3650 9(2 17-Sep-2002 955 3575 20( 566 3625 ~ 0 100 $C 336 3650 135 548 3650 38( 547 3650 22.'699 3650 lie I $-5ep-2002 967 3575 191 573 3625 ( 0 I00 8(~ 361 3625 135 554 3650 38( 556 3650 211 709 3650 19-$ep-2002 953 3600 191 561 3600 C 0 50 8( 367 3600 140 543 3650 37.' 547 3650 20( 698 3650 105 20-5ep-2002 975 3550 181 574 3600 ( 0 50 8( 391 3600 131] 561 3650 37.' 574 3650 20( 717 3650 21-$ep-2002 961 3550 171 568 3625 ( 0 50 8( 379 3600 131] 546 3650 351 557 3675 20( 697 3650 loC 22-Sep-2002 966 3550 17.~ 574 3600 C 0 50 8C 382 3600 1313 548 3650 35{ 560 3650 200 705 3650 101 23-$ep.2002 941 3550 17( 567 3600 0 50 8( 366 3600 131 543 3650 35( 545 3675 200 691 3650 101 24-$ep.2002 956 3550 171 570 3600 0 50 8f 367 3600 131] 544 3650 35( 552 3675 200 695 3650 10C 25-$ep.2002 947 3550 16( 558 3600 0 50 8( 363 3600 131 54.1 3650 35( 556 3675 200 691 3650 loc 26-Sep.2002 953 3550 16( 569 3600 0 100 7( 363 3600 1313 539 3650 37: 545 3650 200 691 3650 95 27-S¢p-2002 954 3550 15'. 566 3600 0 100 8( 370 3600 13C 540 3650 37: 550 3650 200 692 3650 95 25-Sep-2002 964 3550 141 560 3600 0 100 8( 370 3600 13C 546 3650 37.~ 558 3650 200 701 3650 95 29-S¢p-2002 947 3550 151 566 3600 0 100 8( 359 3600 13C 532 3650 375: 541 3650 200 695 3650 10C 30-Sep-2002 954 3550 141 555 3625 0 100 7( 364 3625 13C 538 3650 350 547 3650 190 704 3650 9C TOTAL 25,678 17,358 ,0 10,912 16,427 16,646 21,102 MAXIMUM 3,625 285i 3,650 ( 100 8C 3,650 15~ 3,650 400 3,675 250 3,650 AVERAGE 956 3,590 202' 579 3,612 0 88 7c. 364 3,620 136 548 3,648 379 555 3,653 212 703 3,650 112 # DAYS 30 30 0 30 30 30 30 10/1472002 · SCANNED 1 0 WATER INJECTION REPORT PLATFORM A I DISPOSAL WELL June-2002 A33-1 I!LS A41A-I ILN A44-I 1 Al 1-13R2 Al 1-12 A33-14 A44-02 DATE & NOTES INJ ]Nil l~/J ]NJ ANNU I/qJ l~/J ANNU RqJ ]NJ ANNU INJ ]NJ ANNU ]NJ ]NJ ANNU I~J ]NJ A/qNU 01-Jun-2002 1077 36~0 12C 628 3600 0 0 100 12¢ 344 3600 15 625 3650 15( 636 3600 0 724 3650 02-$un-2002 I089 3,6~0 12C 624 3600 0 0 I00 12¢ 349 3600 15 621 3650 15( 628 3600 0 717 3650 03-Jun-2002 1081 36~5 13C 612 3600 0 0 I00 12C 352 3600 15 617 3650 15( 615 3600 0 718 3650 04-Jun-2002 1105 3~25 14C613 3600 0 0 100 12C352 3600 15 609 3650 15{ 624 3600 0 710 3650 05-Jun-2002 1033 3600 I,K606 3600 0 0 100 12~ 352 3600 15 6~0 3650 15( 584 3600 0 706 3650 06-Jun-2002 1070 3¢t00 14~ 621 3600 0 0 100 11£358 3600 10 607 3650 16{ 609 3600 0 717 3650 07-Jun-2002 1072 3¢~5 15C 623 3600 0 0 I00 115 361 3650 15 606 3650 195 604 3650 0 724 3650 08-Jun-20~2 1076 3¢ t6{ 610 3600 0 0 100 115 366 3600 15 620 3650 20( 614 3650 0 729 3650 09-Jun-2002 1064 3625 16{ 591 3600 0 0 100 115 360 3625 15 603 3650 20( 604 3650 0 721 3650 10Jun-2002 1075 3~25 16C619 3600 0 0 100 115 364 3625 15 613 3650 20( 619 3650 0 733 3650 I l-Jun-2002 1056 36~25 165 606 3600 0 0 100 115 360 360 15 600 3625 20( 599 3650 0 721 3650 12-Jun-2002 1072 3~25 17C 609 3650 0 0 100 115 358 3625 15 612 3650 20( 614 3650 0 732 3650 13-Jun-2002 1052 3425~ 170 590 3650 0 0 100 115 352 3625 15: 598 3650 20( 597 3650 0 715 3650 14-Jun-2002 1065 36~5 17C599 3650 0 0 100 115 354 3625 151611 3650 20( 607 3650 0 730 3650 15-Jun-2002 1049 3~25 17C 557 3650 0 0 100 115 350 3625 15 590 3650 20( 582 3650 0 713! 3650 16-Jun-2002 1050 3625 21C 552 3650 0 0 100 115 31~- 3625 110 591 3650 20( 587 3650 0 707: 3650 17-Jun-2002 I057 3625 21C 597 3650 0 0 100 115 344 3625 110 604 3650 20( 613 3650 0 723! 3650 18-Jun-2002 1056 3625 21~ 585 3650 0 0 100 115 342 3625 110 601 3650 20( 602 3650 0 727'; 3650 19-Jun-2002 1053 3625 210 569 3650 0 0 100 115 347 3625 110 596 3650 20( 596 3650 0 721~i 3650 20-Jun-2002 1049 3625 210569 3650 0 0 100 4~ 344 3625 110 596 3650 175 595 3650 0 7231 3650 2 l~Jun-2002 1049 3625 210569 3650 0 0 100 4~ 345 3625 I10 597 3650 175 598 3650 ~ 728! 3650 22-Jun-2002 1040 3625 225560 3625 0 0 I00 4~ 341 3625 110 590 3650 20( 591 3650 0719 3650 23-Jun-2002 1046 3625 ~25559 3625 0 0 100 4~ 316 3625 115 588 3650 2~ 588 3650 ~ 717, 3650 24-Jun-2002 1043 36~25 225 561 3625 0 0 100 ,~ 344 3625 11: 584 3650 20( 579 3650 ~ 713 3650 25-Jun-2002 1044 3625 24~ 560 3625 ~ 0 100 50 346 3625 11.' 585 3650 20~ 584 3650 712 3650 26-Jun-2002 1046 3625 250563 3625 '~ 0 100 50 359 3625 11.'586 3650 20~ 587 3650 711 3650 27-Jun-2002 1044 3625 24-5 562 3625 ~ 0 100 50 365 3650 11{ 587 3650 20~ 591 3650 717 3650 28-Jun-2002 1034 3625 26~ 561 3600 0 100 50 366 3650 11( 577 3650 225 573 3650 703 3650 29-Jun-2002 1044 3625 255565 3600 0 100 50 385 3650 11( 586 3650 20( 591 3650 712 3650 £ 30-$un-2002 1037 3625 270 561 3600 0 I00 50 380 3650 10( 577 3650 225 572 3650 700 3650 TOTAL 31,728 I 17,601 0 10,570 17,977 17,983 21,543 MAXIMUM 3,625 270 3,650 100 120 3.650 115 3,650 225 3,650 £ 3,650 0 AVERAGE 1,058 3,621 191 587 3,622 0 100 90 352 3,515 62 599 3,649 190 599 3,640 £718 3,650 0 # DAYS 30 [ 30 0 30 30 30 30 07/I 1/2002 SCANNEU MAR i 0 2003 WATER INJECTION REPORT PLATFORM A DISPOSAL WELL Augusl-2002 A33-1 ILS A41A-! ILN A44-11 Al 1-131~ Al 1-12 A33-14 A44-02 DAT~ & NOTES INJ [NJ AN~U ]l~J I~J INJ II~J A~NU II~J I~J ANNU INJ I~J INI INJ II~J OI-Aug-2002 959 3625 41( 599 3650 0 100 7(] 382 3650 13.~545 3650 350 545 3650 225 683 3650 12( 02-Aug-2002 995 3625 40( 607 3650 0 100 7(] 377 3650 13.~554 3650 350 559 3650 225 700 3650 03-Aug-2002 lOOl 3625 39.' 614 3650 0 70 75 377 3650 (4( 557 3650 350 562 3650 225 709 3650 12.~ (N--Aug-2002 993 3625 39( 603 3650 0 100 8(~ 377 3650 14( 554 3650 375 564 3650 225 702 3650 12.~ 05-Aug-2002 993 3625 37.' 603 3650 0 70 8(3 382 3650 13.' 558 3650 350 570 3650 225 703 3650 12.' 06-Aug-2002 993 3625 37.~ 608 3650 0 75 8(] 384 3650 13.~ 560 3650 350 568 3650 225 708 3650 07-Aug-2002 1012 3625 35.' 608 3650 0 75 8(3 334 3650 15( 562 3650 350 581 3650 20~ 706 3650 12( 08-Aug-2002 1000 3625 35.' 602 3650 0 75 8(] 321 3650 15( 560 3650 350 570 3650 20~ 699 3650 12( 09-Aug-2002 987 3625 35.' 609 3650 0 75 8(] 317 3650 15( 555 3650 350 569 3650 200 699 3650 12£ 10-Aug-2002 996 3625 34( 606 3650 0 75 8(] 277 3650 17( 557 3650 320 577 3650 20~ 698 3650 11 -Aug~2002 992 3625 34( 598 3650 0 75 8(] 266 3650 17( 556 3650 320 571 3650 200 694 3650 12( (2-Aug-2002 930 3625 34( 560 3650 0 75 8(] 254 3650 17( 527 3650 320 565 3650 200 656 3650 12( 13-Aug-2002 987 3625 34( 573 3650 0 75 8(] 322 3650 17( 561 3650 320 632 3650 200 691 3650 12( 14-Aug-2002 1085 3625 34( 629 3650 0 75 813 464 3650 17( 727 3650 320 798 3650 20~ 814 3650 12( 15-Aug-2002 999 3650 29( 626 3650 0 I00 813 406 3650 12.' 617 3650 350 605 3650 200 749 3650 75 16-Aug-2002 992 3650 30.' 626 3650 0 100 8(] 399 3650 (3( 603 3650 375 596 3650 200 740 3650 17-Aug-2002 984 3625 31( 620 3650 0 100 8(] 398 3650 13( 592 3650 375 580 3650 200 735 3650 10( 18-Aug-2002 973 3625 32( 620 3650 0 I00 8(] 388 3650 13.~ 578 3650 400 567 3650 21(] 721 3650 II£ 19-Aug-2002 978 3625 31( 617 3650 0 100 8(] 388 3650 13.' 584 3650 400 580 3650 200 718 3650 12£ 20-Aug-2002 975 3625 31( 613 3650 0 100 8(] 390 3650 13.' 581 3650 400 575 3650 200 718 3650 12£ 21 -Aug-2002 994 3625 30( 618 3650 0 100 8(] 410 3650 13.' 594 3650 390 593 3650 200 728 3650 I15 22-Aug-2002 986 3650 29( 616 3600 0 100 8{3 410 3625 12.' 590 3650 400 586 3650 200 718 3650 23-Aug-2002 965 3625 29.' 613 3600 0 100 8(] 398 3625 13( 569 3650 400 561 3650 200 713 3650 12£ 24-Aug-2002 (028 3625 29.' 6[5 3600 0 100 8(] 405 3650 13( 578 3650 400 574 3650 200 715 3650 12£ 25-Aug-2002 919 3625 29.'614 3600 0 100 8(] 401 3625 13( 568 3650 400 559 3650 225 714 3650 12( 26-Aug-2002 972 3625 29.' 6[5 3600 0 100 8(] 404 3625 13{ 571 3650 400 566 3650 225 711 3650 12£ 27-Aug-2002 968 3625 29( 6[7 3600 0 100 8(] 406 3625 13( 568 3650 400 562 3650 225 723 3650 12£ 28-Aug-2002 955 3625 29.' 602 3600 0 100 8(] 396 3625 13f 557 3650 400 549 3650 225 693 3650 29-Aug-2002 96[ 3625 29.' 611 3600 0 100 8(] 397 3625 13.' 560 3650 400 551 3650 225 707 3650 30-Aag-2002 974 3625 28.' 60,$ 3600 0 100 8(] ,~O1 3625 13.s 570 3650 400 565 3650 225 717 3650 14~ 31 -Au~-2002 987 3625 28( 606 3600 0 100 80 ~ 3625 13.~ 579 3650 ~ 588 3650 225 717 3650 laC TOTAL 30,533 18,872 0 I 1,640 17,792 17,988 22,099 MAXIMUM 3,650 4(( 3,650 C 100 80 3,650 17C 3,650 400 3,650 225 3,650 1'~ AVERAGE 985 3,627 32~ 609 3,634 ¢ 0 91 79 375 3,643 14C 574 3,650 370 580 3,650 211 713 3,650 119 #DAYS 31 31 0 31 31 31 31 09/16/2002 ? SCANNED NAR 1 0 2003 ( MEMORANDUM ( State of Alaska Alaska Oil and Gas Conservation Commission TO: Dan Seamount Commissioner DATE: September 20, 2000 THRU: Blair Wondzell P.I. Supervisor FROM: Chuck Scheve~ Petroleum Inspector NON- CONFIDENTIAL SUBJECT: Mechanical Integrity Tests Cross Timbers Platforms A and C Middle Ground Shoal Packer Depth Pretest Initial 15 Min 30 Min. I WellI A33-14 I Typelni. I S I T.V.D. 17982 I~u~,,~l ~00 I~00 I~00 I~00 I lntervall WI P.T.D.I 167O680 ITypetestI P ITestpsil 1996 I Casin~ll 0 I 2200 I 2200 I 2200 I P/F I F, I Notes: I I Type,ni.I S I T.V.D.I ~ I~u~'"~l ~oo I ~oo I ~oo I ~oo I,nterva, I W { WellI A44-02ITypetestl P ITestps~l 2039 ICasingI 0 I 21501 21251 21251 P/F I --P I P.T.D.I 1840750 Notes: WellI C24A-14 [Typelni. I sI T.V.D. I ~4°~ ITue'"~I ~001 ~00 I ~001 ~00 I~nte~a~l W P.T.D.I 1871260 Type testI P I Testpsil 2101 ICasingl 0 122001220012200I P/Fl e I Notes: Notes: Notes: Type INJ. Fluid Codes F = FRESH WATER INJ. G = GAS INJ. S = SALT WATER INJ. N = NOT INJECTING Type Test M= Annulus Monitoring P= Standard Pressure Test R= Intemal Radioactive Tracer Survey A= Temperature Anomaly Survey D= Differential Temperature Test Interval I= Inibal Test 4= Four Year Cycle V= Required by Vananoa W= Test during Workover O= Other (describe in notes) Test's Details I traveled to Cross Timbers Platforms A and C and witnessed the initial MIT on recently re, completed wells A33-14, A44-02 and C24A-14. All three wells were found to have stable pretest tubing and casing pressures. The 30 rain pressure tests were then completed with all 3 wells demonstrating good mechanical integrity. .I.T.'s performed: _3 Attachments: Number of Failures: O_. Total Time during tests: _3 CC: MIT report form 5/12/00 L.G. Vlj77rjh.xls 9/21/00 ~ Cross Timbers Operating Company September 5, 2000 Alaska Oil & Gas Conservation Commission Attn: Tom Maunder 3001 Porcupine Drive Anchorage, Alaska 99501 Revised Sundry Well Operation MGS A33-14 Dear Mr. Maunder' Attached is a revised form 10-404 for the above referenced well We have corrected the permit number and added the liner to surface. If you have any other questions, please call me at (405) 232-4011. Brent Roberson Sr. Engineering Tech. RECEIVED SEP 1 t LO00 A~as~aO~i ~ · ' Attachment~tr Cc. Charles Pope- OKC Bill Miller - Kenai, Ak 210 Park Avenue, Suite 2350, Oklahoma C~ty, Oklahoma 73102-5605 (405) 232-4011 Fax (405) 232-5538 · ( STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS I Operations performed Operation shutdown Stimulate Pull tubing ~ After casing . 2 ~Name of _Operator /5 [,ross Timber's 0peratinq Company 3 Address 210 PARK AVE., 5TE 2350, OKLA. CITY, OK. 7310 Plugg~ng~ Perforate Repmr well Other X Type of Well Development Exploratory Strabgraph~c ~ Service X. Location of well at surface Leg 4, Cond. 30@1561'FNL& 385'~L of Sec. 11,TSN,R13W,$H 6 Datum elevation (DF or KB) 116' KB 7 Unit or Property name Hidd]e Ground Shoal 8 Well number A33-14 feet At top of productive interval 9061'@3008' $ & 1417'W of NE At effecbve depth cnr. of Sec. 14,T8N,R13W,SM At total depth 10555'@ 3527' $ &1934'W of NE Cnr of Sec. 14,T8N,R13W,SM 9 Permit numbe~appmval number 67-68 10 APl number 50- 733-20057-00 11 F~eld/Pool MGS/ "G" Pool 12 Present well condition summary Total depth measured true vertical Effective depth measured true vertical 10,555 8816' 10432' 8705' feet feet feet feet Plugs (measured) Junk (measured) ORIGINAL Casing Structural Conductor Surface Intermediate Production Liner Perforation depth Length 1,871' 10,531' Size 10 3/4" 7" 1476' 5" measured .5" 9,715' - 10,419' true vertical Cemented Measured depth True verhcal depth 1500 SX "G" 1,871' 1,739' 1100 SX "G" 10531' 8,795' 8073' - 8693' Tubing (s~ze. grade, and measured depth) 2-3/8", 4.7#, N-80 EUE AB HOD to 9,610' Packem and SSSV (fype and measured depth) Baker DB Packer @9,610' 150 SX "G" 650 sx. "G" 8956' - 10,432' 7,438' -8,705' 0'- 8,956' RECEIVED SEP 11 2.000 Alaska & Gas Cons. C0mm ion 13 Sbmulabon or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure REPLACE TUBING & REPAIR TREE FAILURE 14 Representative Dady Average Producbon or Injecbon Data Od-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing pressure Prior to well operation 0 0 0 45 1750 Subsequent to operation 0 0 1146 105 3450 15 Attachments 16 Status of well clasmflcat~on as Cop~es of Logs and Surveys run ~ Da,ly Report of Well Operations X Oil Gas Suspended Serv, ce_X to i of m edge Revised T~tle Sr. En -ineerqng Tech Date 09/5/2000 SUBMIT IN DUPLICATE - 44- ~-~ 17 I hereby certify that the.f, or)ego~ng ~s true and correct to the best of my knowledge S,gned'~'~'~-r~ l ~'~~~ Form 10-404 Rev 06/15/88 ¢ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS I Operations performed Operabon shutdown Stimulate Plugg~ng~ Perforate Pull tubing ~ After casing Repair well Other X 2 Name of Operator ~5 Type of Well Cross Timbers 0peratinq Company l Development Exploratory 3 Address Strabgraph~c 210 PARK AVE., STE 2350, OKLA. CITY, OK. 7310 Service Location of well at surface Leg 4, Cond. 30~a1561'FNL& 385'~L of Sec. 11,TSN,R13W,$M At top of producbve ~nterval 9061'~3008' $ & 1417'W of NE cnr. of Sec. 14,T8N,R13W,$M At effechve depth At total depth 6 Datum elevation (DF or KB) 116' KB 7 Umt or Property name Middle Ground Shoal feet 8 Well number A33-14 9 Permit number/approval number f~'% 9F.- 68 10 APl number 5o- 733-20057-00 11 Field/Pool 10555'[a 3527' S &1934'W of NE Cnr of Sec. 14,T8N,R13W,SM ~'~/ "G" Pool 12 Present well condition summary '/ ~ Total depth measured 10,555 feet Plugs (measured) true vertical 8816' feet 1 U I~ I L~I I~I/A L Effective depth measured 10432' feet Junk (measured) ~, // true vertical 8705' feet Cas,ng Length S,ze Cem~ted Measu~.~~ True vert, cal depth Structural Conductor Surface 1,871' 1~ 1500 SX "G~, 1,871' 1,7391 Intermedmte 10,531' 7~,,,~-~ 1100 SX "G"~ 10531' 8,795 Production ~ L,ner 1476' 5" ~50 SX "G" ~95~6' - 10,432' 7,438' -8,705' Perforation depth measured {~ ~, · 9,715' - 10,419' ' . .- true vert, ca, ~ ~ RECEIVED Tubing (size, grade, and measured depth) t " 2-3/8 , 4.7#, N-80~EUE AB MOD tt~9<6~0' Packers and SSSV (type and measured depth) 1 Baker DB Packer @9'6~10' '~' 13 St,mulat, on or cem'~squeeze summary Intervals treated (meas'~) Treatment description ~nclu~p.~volumes used and hn~l pressure REPLACE TUBING & REPAIR TREE FAILURE / 14 '"'~epresent~~ ve GDaa I;_YMAcVfe rage Pr;;;eC117;b~r, nj eC;laO~ nDga tpares s u re Tub lng pressure Pnor to well operahon 0 0 0 45 1750 Subsequent to operation 0 0 1146 105 3450 15 Attachments Cop~es of Logs and Surveys run ~ Dady Report of Well Operations X 16 Status of well classification as Od Gas Suspended Service X · O S,gne~ ~' ) ~'' ¢,' T,tle Sr. Engineering Tech Date 08/25/2000 SUBMIT IN DUPLICAT~ Form 10-404 Rev 06/15/88 - 44 - Today's Date 814100 WELL NAME: MGS A # 33-14 RIG NAME: XTO PLATFORM A FIELD NAME: MIDDLE GROUND SHOALS EVENT No.: 1 AFE No.: 2000169 WELL ID No.: MGS A # 33-14 APl No.: 50-733- EVENT DESC.: REPAIR TUBING & TREE FAILURE AND P DATE: 6/28/00 DSS: 1 DEPTH: 0 MUD WT: CUM COST TO DATE: $49,431 HOURS PH O__~P 14 00 C RS 3 00 C OT 7 00 C OT A.CT ACTIVITY DESCRIPTION RU DOWELL CTU TEST CTU BOP'S TO 4000 PSI AND BHA, TWO HYDRAULIC-DISCONNECTS FAILED DRESSING TWO MORE, WILL BE ON 1ST CHOPPER IN A M BACK FLOW WELL, PREPARE TO RIH WITH UNDERREAMER BAKER DATE: 6/29/00 DSS' 2 DEPTH: 0 MUD WT' HOURS P__~H O._.~P 2 50 C OT 0 50 C OT 1 25 C OT 0 50 C OT 1 25 C OT 3 00 C OT 1 50 C OT 3 00 C OT 1 50 C OT 1 00 C OT 2 50 C OT 2 50 C OT 3 00 C OT ACT ACTIVITY DESCRIPTION MAKE UP AND PRESSURE TEST BHA, PRESSURE TEST 8OP BODY TO 5000 PSI HELD SAFETY MTG W / RIG CREW, PRODUCTION AND CTU CREW RIH W / BAKER UNDER REAMER- 2 37 OD TAG FILL AT 5809', WORK DOWN TO 6072', UNABLE TO GO DEEPER POH TO P/U DRAG BIT OUT OF HOLE, PU 2 7" DRAG BIT RIH W / BIT & MTR HARD MILLING F / 6250 TO 6580', MILL STOPPED @ 9820', POSSIBLE MOTOR FAILURE POH PU UNDER REAMER & MTR RIH TO 9000' START UNDER REAMING, MAKING 2 PASSES F / 9600' TO 9700' AT 15 FPM TAG & STALL MTR @ 9744', PU AND START UNDER REAMING SLOWLY TO 10372' UNABLE TO GET ANY DEEPER (RECORED H2S AT THE WELL 3500 PPM, ADDING SCHVENGER, BRINGING H2S DOWN TO 0 TO 250 PPM BEFORE GOING TO PRODUCTION) DATE: 6/30/00 DSS: 3 DEPTH: 0 MUD WT: I HOURS PH O._~P 0 75 C OT 3 25 C OT 0 5O C OT 3 00 C OT 2 50 C OT 4 58 C OT 2 42 C OT 1 00 C OT 3 00 C OT 2 50 C OT 0 50 C OT ACT ACTIVITY DESCRIPTION POH W/UNDER REAMER STUCK UNDER REAMER AT 8749- PACKED OFF - ATTEMPT TO DISCONECT - DROPPED BALL & PRESSURE UP TO DISCONNECT BHA - WORKED PIPE FREE RIH - PIPE STOPPED AT 8873' POH, MOTOR & UNDER REAMER WERE STILL ON COILED TUBING M/U TOOL STRING - W/DOWELLS JET BLASTER W/2 63 OD GR RIH TO 8976 W/JET BLASTER (PUMPING) WASH 3 1/2 TAIL PIPE AND 5" LINER TO 9700' - PUMP 9 BBL SWEEP MAKE SECOND PASS TO 9700' - PUMP SECOND 9 BBL SWEEP POH (PUMPING) BREAK OFF JET BLASTER - M/U BAKER THRU TBG 2 5" BY 5" INFLATABLE RET BP RUNNING IN HOLE W/INFLATABLE BP (PUMPING) DATE: 7/1/00 DSS: 4 DEPTH: 0 MUDWT: J HOURS PI..I O__~P 2 00 C OT RIH W/INFLATABLE BP (PUMPING) Page 1 AUG 29 2000 Copynght © 1993-98 by Epoch Wells~te Se~ices, Inc. All nghts rese~ed~,.~,~ ~j,~. ~ ,~" ~.~ C,~l~~n ' ' Anchorage Today's Date 8~4~00 WELL NAME: MGS A # 33-14 RIG NAME: XTO PLATFORM A FIELD NAME: MIDDLE GROUND SHOALS EVENT No.: 1 AFE No.: 2000169 WELL ID No.: MGS A # 33-14 APl No.: 50-733- EVENT DESC.: REPAIR TUBING & TREE FAILURE AND P DATE · 7/1/00 DSS: 4 DEPTH: 0 MUD WT: HOURS PH O__~P 1 50 C OT 0 50 C MD 3 50 C OT 4 50 C RS 1 00 C OT 0 50 C OT 0 50 C OT 1 50 C RS 3 00 C NT 5 50 C NU ACT ACTIVITY DESCRIPTION SET BP @ 9650' CT MEAS MONITOR WELL F/30 MIN - NO PRESSURE BUILD - LOOKS GOOD POOH W/CTU & CONTINUE PUMPING 1 5 BPM RIG/DOWN CTU FROM FLOOR, WELLHEAD ROOM & PIPE DECK SET BPV - TBG SLIGHT VAC - ANN = SLIGHT FLOW NO PRESS BLEED ANN TO PROD ATMOS TANK 1/2 HR - FLOW STOPPED PULL BPV (TBG SIDE STATIC) - RE-INSTALL BPV MOVE CT SPOOL & CONTROL HOUSE TO LOWER DECK NIP/DN TREE - BRK/FREE W/25K BEFORE REMOVE CLAMP - LY/DN TREE NIP/UP RISER & BOPB DATE: 7/2/00 DSS: 5 DEPTH: 0 MUD WT: HOURS 18 00 6 00 PH OP C NU C NU ACT ACTIVITY DESCRIPTION NIPPLE/UP BOPE, UNLOAD BOAT @ "A" - BACK/LOAD BOAT @ "C" (CREWS & CRANE OPERATORS SPLIT BETWEEN PLATFORMS, SLOWING DOWN NIP/UP OPER ) CONTINUE NIP/UP BOPE - PREP TO TEST SAME @ "A" - PREP FOR SKIDDING OF SCHLUMBERGER & BJ UNITS & BACKLOADING OF BOAT @ "C" DATE: 7/3/00 DSS: 6 DEPTH: 0 MUD WT: HOURS PH O_~P 1 00 C TB 3 50 C TB 0 50 C TB 1 00 C TB 2 50 C TB 11 00 C TB 1 00 C OT 1 00 C OT 2 50 C CA ACT ACTIVITY DESCRIPTION FUNCTION TST BOP - M/U TST JT & SCREW/INTO HANGER (3 1/2 TURNS ONLY AS HANGER THREADS ARE MOSTLY DETERIATED) WORK/QN & REPAIR KOOMEY REMOTE LIGHTS - R/U DOWELL TO KILL LINE FOR TEST PUMP THRU CHK MANIFOLD W/DOWELL & CHK FOR LEAKS ATTEMPT PIPE RAM TEST - FLOW ON ANNULUS - BK/OUT TST JT, CLOSE BLINDS & BLEED ANNULUS FRM/35 PSI TO 3 PSI IN PROD ATMOS TANK - HANGER SEALS HAVE FAILED PULL BPV (THREADS RATTY) - ATTEMPT TAP THREADS IN PROFILE - NO GO - ATTEMPT INSTALL 2-WAY CK o NO GO - ATTEMPT TO RE-INSTALL BPV - NO GO CALL MR BLAIR WONZELL OF AGOGCC & HE CONCURRED THAT WE HAD A NO FLOW WELL & TO A PARTIAL BOP TST - TST'D ANN W/ BLINDS CLSD 250/500 PSI & ALL BUT RAMS TO 250/5000 PSI - REPAIRS MADE TO MUD PUMP VALVE & T/DRV R/U TBING SPEAR ASS'BLY & R/U ANN TO PROD SPEAR TBG BELOW HANGER & PULL HANGER & TBG FREE W/125K- STRING WT = 100K- DOUBT IF WE GOT IT ALL - PULL HANGER TO FLOOR & LY/DN R/U & CIRCULATE WELL TO PRODUCTION @ 2 BPM DATE: 7/4/00 DSS: 7 DEPTH: 0 MUDWT: HOURS PH 0 50 C 2 00 C 1 00 C 1 00 C O._~P ACT ACTIVITY DESCRIPTION CA CIRCULATE WELL FROM +/- 8900' TAKING RETURNS TO PRODUCTION TILL ENTIRE ANN DISPLACED & SAMPLE REVEALED CLEAN FW RETURNS W / NO H2S MD S / DN, BLEED OFF HEADER, PRESS FROM ANN (60 PSI), MONITOR WELL LD OPEN WELL, BRK/OUT SAFETY VALVE & PULL & LY DN 1 PUP & 1 JT 3 1/2" 8RD TBG & 1 JT 3 1/2" BUTT TBG & SPEAR ASS'BLY OT MU NEW HANGER W / 2-WAY CHK & LAND Page 2 Copyright © 1993-98 by Epoch Wells~te Services, Inc All nghts reserved Today's Date 814100 .............. ........... WELL NAME: MGS A # 33-14 RIG NAME: XTO PLATFORM A FIELD NAME: MIDDLE GROUND SHOALS EVENT No.: 1 AFE No.: 2000169 WELL ID No.: MGS A # 33-14 APl No.: 50-733- EVENT DESC.: REPAIR TUBING & TREE FAILURE AND P DATE: 7/4/00 DSS: 7 DEPTH: 0 MUD WT: HOURS PH OP 9 00 C TB 1 00 C RS 9 5O C LD ACT ACTIVITY DESCRIPTION FILL STACK & TEST BOP PIPES, BLINDS, ANNULAR, MANUAL HCR, HCR & KILL LINE & VALVES 250 / 5000 PSI, LOTS OF LEAKS FROM CLAMPS, HAD TO SERVICE 3' MANUAL CHOKE & REPLACE HCR VALVE, FINALLY OBTAINED GOOD BOP TEST BRK DN TEST TOOLS, RU TO PULL & LY DN TBG, BACK OUT HANGER LOCK DNS, HOLD SAFETY MEETING RE TBG PULL & NORM PULL NEW HANGER TO FLOOR & LY DN, PULL 3 1/2" BUTT TBG, LY DN SAME & CHECK F / NORM JT, # 79 HAD 12" SPLIT (+/- 2450' RKB) DATE: 7/5/00 DSS: 8 DEPTH: 0 MUDWT: HOURS PH O__~P 3 50 C LD 2 50 C RS 2 50 C OT 1 50 C RS 4 50 C RS 0 50 C RS 9 00 C RS ACT ACTIVITY DESCRIPTION PULL 3 1/2" BUTT TBG, LY DN SAME & CHK F NORM, RECOVERED 1 3 1/2" 8RD PUP, 1 JT 3 1/2 8RD X BUTT, 192 JTS 3 1/2" BUTT, 2) X NIPPLES & SEAL ASS'BLY RD TBG TONG EQUIP & SET TEST PUMP & SPOT DOWELL CTU & EQUIP BK LOAD BOAT FINISHED SPOTTING DOWELL CTU & EQUIP RU CTU & RELATED EQUIPMENT CTU OPER WAIT ON BOAT CONTINUE RU CTU & EQUIPMENT WHILE ST LOAD UNLOAD BOAT, SENT BOAT TO "C" FOR WL & CMT UNITS, LOADED ON BOAT, BOAT LEFT FOR BEACH FOR CREW SLEEP @ MID PM THIS SHOULD END OUR SPLIT CREWS AS WE HAVE BROKE DOWN & SKIDDED WL & BJ UNITS ON "C" SO THEY COULD BE OFF LOADED W / SMALL CRANE AS LARGE CRANE IS STILL DOWN DATE: 7/6/00 DSS: 9 DEPTH: 0 MUD WT: HOURS PH O_.~P 0 50 C RS 1 50 C TB 1 50 C NU 2 50 C TB 3 00 C TB 2 00 C RS 0 50 C OT 0 50 C OT 2 50 C OT 2 50 C OT 0 50 C OT 2 00 C OT 1 00 C OT 2 00 C OT 1 00 C OT 0 50 C OT ACT ACTIVITY DESCRIPTION FINISH RU CTU ATTEMPT TST CTU BOP'S AGAINST RIG BLINDS CLOSED, NO TEST SET BK CTU INJECTOR HEAD & ND BOP'S OPEN RIG BLIND RAM DOORS, RUBBERS BAD RIH W HANGE W / 2-WAY CHK & LAND IN WELLHEAD, CHANGE OUT BLIND RAM RUBBERS, RE-TEST BLINDS TO 250 / 5000 PSI, OK PULL HANGER FROM WELLHEAD BLIND FLANGE OFF CTU'S BOP & TEST 250 / 5000 PSI, OK NIP UP XO SPOOLS & KILL LINE MU BAKER INFLATABLE BP RETRIEVING TOOL (W/3 3/8" CUT LIP GUIDE) & TEST, OK RIH, HAVE TO WORK PAST WELLHEAD @ 38', POOH & STRAIGHTEN CT, RIH, WORK THRU LEDGE @ WELLHEAD @ 38', RIH TO 300', SET DN W / -6000 LBS POOH & CHK BAKER O'SHOT GUIDE, GRIND SHARP EDGES FROM SAME RIH & WORK PAST LEDGE @ WELLHEAD @ 38', RIH & SET DN @ 260' - 7000 LBS, NO GO, POOH & BRK OFF TOOLS, BAD GROOVES IN O'SHOT GUIDE WAIT ON 6" LIB FROM BEACH & NIP DN XO SPOOL & MU TO CT RIH W 6" LIB, UNABLE TO GET PAST WELLEAD @ 38', POOH ND XO SPOOL, REMOVE 6" LIB, - NU XO SPOOL MU 2 50" SPRAY NOZZLE (ROUNDED & SMOOTH) & RIH, UNABLE TO PASS WELLHEAD @ 38', POOH HAVE WELDER SMOOTH OUT & GRIND 3 3/8" O'SHOT GUIDE, RIH, UNABLE TO PASS WELLHEAD @ 38', POOH REMOVE O'SHOT GUIDE FROM CT, SHOWS FLAT LEDGE @ WELLHEAD, SET BK INJECTOR HEAD SD, WILL ATTEMPT SLICKLINE RUN ?.~¢ ~¢~,. - "~"" WAlT ON CHOP PERS & SLICKLIN E PERSON N EL - ~,..~,~=" '~.~ ~V E D~ Page 3 Copyright © 1993-98 by Epoch Wellsite Services, Inc All rights reserved tr Today's Date 8~4/00 WELL NAME: MGS A # 33-14 RIG NAME: XTO PLATFORM A FIELD NAME: MIDDLE GROUND SHOALS EVENT No.: 1 AFE No.: 2000169 WELL ID No.: MGS A # 33-14 APl No.: 50-733- EVENT DESC.: REPAIR TUBING & TREE FAILURE AND P DATE · 7/7/00 DSS: 10 DEPTH: 0 MUD WT · HOURS PH O._~_P 2 00 C RS 4 00 C OT 1 50 C RS 1 50 C WY 0 50 C RS 2 00 C OT 3 00 C TR 0 50 C WA 3 00 C CA 0 25 C OT 3 25 C TR 1 00 C OT 1 50 C RS ACT ACTIVITY DESCRIPTION DRAIN STACK & CHK WELLHEAD BEGIN TO RU SLICKLINE UNIT FROM WELLHEAD RM & FLY PERSONNEL TO "C" TO CANIBALIZE HYD HOSES WAIT ON WEATHER (FOGGED IN & UNABLE TO FLY SLICKLINE PERSONNEL TO PLATFORM FINISH RU SLICKLINE & MU TOOLS RIH W / 1 3/4" LIB TO 400' & VERIFY NO BAD CASING @ SURFACE, POOH, RIH W / 2 1/4" LIB & TAG T / 5" LINER @ 8954' WLM WORK INTO LINER & RIH TO 8978' WLM, SET DN ON FILL (?) UNABLE TO PROCEED, POOH RD SLICKLINE UNIT BRK DN CT TOOLS & MU NEW BHA (CT TOOLS XO TO 1 1/2" MT WEIGHT BARS TO HOLD BAKER O'SHOT GUIDE AWAY FROM WALL OF CASING) RIH, WORK THRU WELLHEAD @ 38', RIH W / NO TROUBLE W / CASING, TAG FILL @ 9538' (INSIDE 5") PU TO 9538' ESTABLISH CIRCULATION & WSH FILL TO 9625' CT MEAS PUMP 20 BBLS HI-VIS SWEEP & POOH TO 2920', BK DN TO 9625' STOP CIRC, CLOSE WELL IN, RIH & TAG INFLATABLE BP @ 9667' CT MEAS, CATCH SAME & DEFLATE POOH W / PLUG & AS PRESS CAME AROUND PLUG TO 900 PSI, FLOW WELL TO PROD PLUG @ SURFACE, SHUT IN WELL & R OFF WELL W INJECTOR HEAD & LD BHA & BP RD CTU, WELL PRESSURE BUILT TO 1375 PSI IN 1 HOUR, FLOW TO PRODUCTION, PRESSURE DECREASED TO 0 PSI DATE: 7/8/00 DSS: 11 DEPTH: 0 MUDWT' HOURS PH O._~P 4 50 C RS 1 50 C OT 2 50 C OT 1 50 C OT 1 00 C OT 8 00 C WY 1 50 C WY 3 00 C WY 0 50 C WY ACT ACTIVITY DESCRIPTION FINISH RD CTU & DISPLACE COIL W N2, SHUT IN WELL, BUILT TO 1375 PSI IN 1 HR, FLOW TO PROD, PRESS DECLINED TO 0 PSI MOVE CTU & MAKE ROOM F SCHLUMBERGER UNIT BACK LOAD BOAT W / CTU & EQUIPMENT WAIT FOR TIDE CHANGE, MOVE SCHLUMBERGER EQUIP BACK LOAD BOAT RU SCHLUMBERGER, TEST LUBRICATOR TO 2500 PSI, OK TROUBLE SHOOT E-LINE TOOLS SAFETY MEETING, ARM TOOLS, PU BAKER 5" PACKER & TAIL PIPE RIH W / PKR ON WL & SET DOWN @ 8970' WLM (CCL), 8983' PKR DEPTH MADE 5 ATTEMPTS TO PASS, NO GO POOH W / E-LINE & PKR & TAILPIPE DATE: 7/9/00 DSS: 12 DEPTH: 0 MUDWT: HOURS PH O._.~P 2 O0 C WY 0 50 C OT 5 00 C RS 2 00 C OT 8 50 C RS 6 00 C TR ACT ACTIVITY DESCRIPTION POOH W / E-LINE & PKR W / TAILPIPE CHECK GAS LEVELS IN LUBRICATOR (MAX 40 PPM CO, 18% LEL - OK 0 BRK DN PKR ASS'BLY, RD SCHLUMBERGER & MOVE OFF PIPE RACK MAKING ROOM F CTU UNLOAD CTU & EQUIPMENT FROM BOAT RU CTU & EQUIPMENT & TEST BOP'S 250/5000 PSI & SPOOL TO 1300 PSI, OK RIH W / BACK REAMER ASS'BLY TO 9400' CTMEAS (INSIDE 5") & BK REAM TO 8935 (INTO 7") & TO 9625' & BK TO 8935', 4 PASSES IN ALL & 6 PASSES @ TOP OF LINER, PUMP 105 BBLS OF HI-VIS SWEEPS Page 4 Copynght © 1993-98 by Epoch Wells~te Services, Inc All rights reserved Today's Date 814100 WELL NAME: MGS A # 33-14 RIG NAME: XTO PLATFORMA FIELD NAME: MIDDLE GROUND SHOALS EVENT No.: 1 AFE No.: 2000169 WELL ID No.: MGS A # 33-14 APl No.: 50-733- EVENT DESC.: REPAIR TUBING & TREE FAILURE AND P DATE · 7/10/00 DSS · 13 DEPTH: 0 MUD WT: HOURS PH O~P 1 50 C CA 2 00 C TR 4 50 C RS 1 00 C NC 3 00 C CT 5 00 C RS 1 00 C BH 2 00 C WY 0 25 C WY 0 25 C MD 1 50 C WY 2 00 C RS ACT ACTIVITY DESCRIPTION CIRC & PUMP HI-VIS SWEEPS WHILE ST BACK REAMING 5" LINER, HAVE TO TAKE RETURNS TO PRODUCTION AS H2S - 3600 PPM POOH W / CT (PUMPING) CHK GAS LEVELS, BRK OUT BHA & RD CTU & EQUIPMENT NU SHOOTING FLANGE FOR E-LINE BACK LOAD BOAT W / CTU & EQUIPMENT, HAUL SLICKLINE UNIT FROM "C" TO "A" SPOT SCHLUMBERGER E-LINE UNIT & EQUIP, RU SAME & TEST LUBRICATOR TO 2500 PSI, MU E-LINE TOOLS ON CATWALK MU PACKER ASS'BLY RIH W / PKR ASS'BLY ON E-LINE, ENTER 5" CASING SMOOTHLY W / NO PROBLEM LOG & LOCATE & SET PKR @ 9610' WL MEAS, GOOD SET SHUT IN & MONITOR WELL 0 PSI, OK POOH CHK FOR GAS LEVELS, OK 0 PSI ON WELL, RD SCHLUMBERGER E-LINE UNIT& EQUIP DATE: 7/11/00 DSS: 14 DEPTH: 0 MUDWT: HOURS PH O._~P 1 00 C NU 1 00 C RS 7 00 C TB 1 00 C OT 1 00 C RS 3 00 C LD 3 00 C RR 7 00 C LD ACT, ACTIVITY DESCRIPTION NIPPLE UP BELL NIPPLE, FLOW LINE & TRIP TANK CLEAR RIG FLOOR OF WIRELINE EQUIP MU HANGER W / 2-WAY CHECK & TST ASS'BLY & RUN & LAND SAME, TEST GAS ALARMS, TEST BOP TO 250 / 3000 PSI W / MR GRIMALDI (AOGCC REP) - OK TEST RUN & SET MUD PUMPS RU TO RUN 2 7/8" PAC DP (743') MU BAKER "F" LATCH PLUG & RUNNING TOOL, PU & RABBIT 2 7/8" DP TROUBLE SHOOT DC POWER PU & RABBIT 3 1/2" DP & RIH W / SAME DATE · 7/12/00 DSS: 15 DEPTH: 0 MUD WT: HOURS PH 5 00 C 1 00 C 1 50 C 0 50 C 0 50 C 1 00 C 3 00 C 1 00 C 0 50 C 0 50 C 3 50 C I 00 C 0 50 C O___~P ACT ACTIVITY DESCRIPTION LD PU, RABBIT 3 1/2" DP & RIH W / SAME RR TROUBLE SHOOT DC POWER, LOAD MTRS & SOLVE PROBLEM RR SERVICE RIG & T DRIVE EQUIP LD PU, RABBIT 3 1/2" DP & RIH W / SAME CA BREAK CIRCULATION, ClRC DP VOLUME CT TAG PKR @ 9620' DPM & SET 'F" LATCH IN & RELEASE FROM SAME CT DUMP SAND DOWN DP & WAIT TO LET SETTLE & TAG T ! SAND @ 9588' DPM TC CLS PIPE RAMS & TEST CASING (7"& 5" TO PKR) 2000 PSI F/15 MIN X2, BOTH TESTS SHOW i80 PSI BLEED DOWN IN 15 MIN TR POOH TO 8900' CA CIRCULATE & FLUSH DP (1 DP VOL) CT RU BELLY FINGER FOR 2 7/8" DP B" HANDLE 2 7/8" DP & STD BK & BRK/OUT BAKER "F" LATCHING ASS'BLY Page 5 ~UG 2 C) 2.000 Copyright © 1993-98 by Epoch Wells~te Services, Inc All rights reservb~[Si':~ ~.. ,~. Today's Date 8~4~00 WELL NAME: MGS A # 33-14 RIG NAME: XTO PLATFORM A FIELD NAME: MIDDLE GROUND SHOALS EVENT No.: 1 AFE No.: 2000169 WELL ID No.: MGS A # 33-14 APl No.: 50-733- EVENT DESC.: REPAIR TUBING & TREE FAILURE AND P DATE: 7/12/00 DSS: 15 DEPTH: 0 MUD VVT: 9 HOURS PH O._~_P 1 00 C BH 0 50 C TC 0 50 C TC 2 50 C TC ACT ACTIVITY DESCRIPTION MU 7" SQZ PKR ASS'BLY RIH TO 929' & SET PKR RU & TEST CASING ABOVE PKR TO 2000 PSI F/15 MIN, NO BLEED, GOOD TST RELEASE PKR & RIH TO 4837' FOR NEXT TEST NOTE CALLED CHARLES POPE ( IN CALIF ) & RELAYED RESULTS OF OVERALL CSG TEST & WE DISCUSSED THE POSSIBILITY THAT WE MAY NOT HAVE TO RUN 5" TO SURFACE, WILL CONTINUE TO CHASE LEAKS IN D 7" & 5" DATE: 7/13/00 DSS: 16 DEPTH: 0 MUDWT: HOURS PH O__~P 4 00 C TC 1 00 C TR 2 00 C TC 1 00 C TR 1 50 C TC 1 00 C TR 1 00 C RR 1 00 C TC 0 00 3 50 C TR 0 50 C BH 4 50 C TR 1 50 C MI 1 50 C TR ACT ACTIVITY DESCRIPTION SET PKR ~ 4837', TST ABOVE 2000 PSI, BLED TO 1820 IN 15 MIN, TST DOWN 2000 PSI, BLED TO 1800 IN 15MIN, DISCUSS W / C POPE & DECIDE TO TST TO 3500 PSI, TST ABOVE 3500, BLED TO 3250 IN 15 MIN, TST DOWN 3500, BLED TO 2300 IN 15 MIN, RELEASE PKR RIH TO 7071' SET PKR & TST ABOVE, BRK DN @ 3400', BLED TO 1600 IN 10 MIN, TST DOWN, BRK DN @ 2900' BLED TO 2100 IN 15 MIN & 1600 IN 45 MIN, RELEASE PKR RIH TO 8007' & SET PKR TST ABOVE, BRK DN @ 2575', BLED TO 1400 IN 10 MIN, TST DOWN 3500, BLED TO 3100 IN 15 MIN RELEASE PKR & RIH TO 8813' ADJUST TOP DRIVE SET PKR @ 8813', TST DOWN 3500 BLED TO 3200 IN 2 MIN, PKR LEAKING, RELEASE & RE-SET @ 8802', ATTEMPT TST DOWN PKR FAILING DISCUSS WITH D SCHULTZE, D MARSHALL & C POPE, DECIDE TO RUN 5" & CMT RELEASE PKR & POOH W / SAME BRK DN RETRIEVAMATIC SQZ PKR & M/U TIW POLISH MILL ASS'BLY FOR T LINER RIH W / TIW POLISH MILL ASS'BLY ON 3 1/2" DP & TAG T TIE BK SLEEVE @ 8950' DPM BRK CIRCULATION & POLISH T TIE BK SLEEVE & D6' RECEPTICAL, MILD TQ ON 1ST PASS & THEN CLEANED UP POOH DATE: 7/14/00 DSS: 17 DEPTH: 0 MUD WT: HOURS PH O__~P 2 50 C TR 0 50 C BH 1 00 C SR 4 00 C WY 1 00 C BH 1 50 C OT 0 50 C OT 0 50 C BH 3 50 C OT 0 50 C BH 4 50 C NU 1 00 C BH ACT ACTIVITY DESCRIPTION FINISH POOH W / TIW POLISH MILL ASS'BLY BRK OUT & LD TIW POLISH MILL ASS'BLY, GOOD EVEN WEAR ON MILLS, LOOKS GOOD SERVICE T DRIVE, CROWN & IRON ROUGHNECK SPOT E-LINE UNIT, RIH & LOG CCL FOR 7" COLLARS, RD E-LINE & REMOVE PU & MU BAKER MECH INSIDE CSG CUTTER BLEED OFF 7"X 10 3/4" ANN (17 PSI) & RU TO CIRC TO PRODUCTION RIH, ATTEMPT CUT 7" CSG @ 88' W / MECH CUTTER, NO CUT POOH & CHG OUT MECH CUTTER FOR HYD CUTTER RIH & CUT 7" CSG @ 88', ATTEMPT TO CIRC TO 7" 10 & 3/4" ANN POOH & LD CUTTING ASS'BLY NIPPLE DOWN BOP & RISER PU & MU 7" SPEAR ASS'BLY & RIH Page 6 Copyright © 1993-98 by Epoch Wellsite Services, Inc All rights reserved ; ,ECEtVED Today's Date 814100 WELL NAME: MGS A # 33-14 RIG NAME: XTO PLATFORM A FIELD NAME · MIDDLE GROUND SHOALS EVENT No.: 1 AFE No.: 2000169 WELL ID No.: MGS A # 33-14 APl No.: 50-733- EVENT DESC.: REPAIR TUBING & TREE FAILURE AND P DATE: 7/14/00 DSS: 17 DEPTH: 0 MUDWT: , HOURS PH O.__~P 1 00 C OT 1 50 C OT 0 50 C NC ACT ACTIVITY DESCRIPTION RIH & SPEAR D7" & NIPPLE DOWN WELLHEAD PULL 7" & WELLHEAD SPOOL TO RIG FLOOR & RELEASE SPEAR & LD & LD 7" & WELLHEAD SPOOL RIH W/NEW WELLHEAD SPOOL & PREP TO NIPPLE UP DATE: 7/15/00 DSS: 18 DEPTH: 0 MUD WT: HOURS PH O__~P 2 00 C NC 1 00 C RC 1 00 C RC 2 00 C RC 1 50 C NC 1 00 C NC 0 5O C NC 7 00 C NU 4 50 C NU 1 00 C TB 2 50 C OT ACT ACTIVITY DESCRIPTION MU NEW WELL HEAD & CSG VALVE MU 7" DRESSING GUIDE, DRESS 7", CUT OFF FROM 88' TO 91' RIG UP TO RUN 7" CSG RIH W / 8 1/8 BY 7 1/8 GUIDE 72" 8 1/8 BY 7" OVERSHOT 1 74, 8 1/8 BY 6 3/8 TOP SUB, 1 12 7" PUP JT 15 17, 1 JT 7" 46 20, PLUS 7" LANDING JT, LATCH ONTO CUT OFF, PULL 110,000 SET SLIPS SLACK OFF CUT OFF 7" CSG, LD LANDING JT & 16 5' CUT OFF, DRESS STUB, RD CSG EQUIP INSTALL 11" 5KX 11" 5K SPOOL FOR 5" CSG NU DOUBLE STD ON RISER, INSTALL RISER NU BOPS OFFLOAD WORK BOAT (5" CSG & ASSN) CHANGE TO 5" RAMS IN BOPS TEST BOPS TRANSFERING BJ CEMENT FROM BOAT TO DECK PREPARE RIG & DECK TO RUN 5" CSG DATE · 7/16/00 DSS: 19 DEPTH: 0 MUDWT: HOURS PH O._~_P 2 50 C OT 2 00 C RS 13 50 C RC 1 50 C RC 0 50 C CA 2 00 C CM 2 00 C NU ACT ACTIVITY DESCRIPTION CLEAR RIG FLOOR, RIG UP CMT HOSE IN DERRICK, STRAP 5" CSG R/U WEATHERFORD CSG TONGS & CHANGE TO LONGER BALES RIH W TIW (MULE SHOE 1 87 - SEALS 4 00), TOP SUB 1 00, ORIFICE COLLAR 73 CROSS OVER JT 29 50, 202 JTS OF 5" 18# 513 HYDRIL 8930', BOW TYPE CENT EVERY OTHER JT STAB INTO SEAL BORE @ 8950', LD 1 JT & M/U CMT HEAD, STAB INTO SEAL BORE, BREAK CIRC TEST SEAL INTEGRITY CIRCULATE CSG VOLUME @ 70 SPM - 500 PSI PRESS TEST LINES TO 4000 PSI, MIX & PUMP 132 BBL 15 8# CLASS G +0 6%FL33+0 3%CD-32 + 0 05%R-I+IGHS FP-6L, DISPLACE W/163 BBL FIW, BUMP PLUG W/3200 PSI DRAIN STACK, PREPARE TO PICK UP STACK TO SET SLIPS ON 5" CSG NOTE TOP OF 5" LINER WAS TAGGED AND STUNG INTO @ 8950' DATE: 7/17/00 DSS: 20 DEPTH: 0 MUD WT: HOURS PH O.._~P 2 00 C NC 1 00 C NC 4 00 C NU 3 00 C NC 7 00 C NU ACT ACTIVITY DESCRIPTION Copynght© 1993-98 by Epoch Wellsite Services, Inc All nghts reserved. DRAIN STACK, RAISE STACK TO SET 5" CSG SLIPS SET 5" CSG SLIPS W 140K HANGING WT, CUT 5"CSG ND BOP & LD RISER FINAL CUT ON 5" CSG, DRESS STUB, NU TBG SPOOL TEST PACK OFF TO 3800 PSI NU BOP, CHANGE RAMS TO 2 3/8", REFAB BELL NIPPLE, CHANGE OUT ELEVATOR BAg.~,~ Page 7 f Today's Date 8/4/00 WELL NAME: MGS A # 33-14 RIG NAME: XTO PLATFORM A FIELD NAME: MIDDLE GROUND SHOALS EVENT No.: 1 AFE No.: 2000169 WELL ID No.: MGS A # 33-14 APl No.: 50-733- EVENT DESC.: REPAIR TUBING & TREE FAILURE AND P DATE: 7/17/00 DSS: 20 DEPTH: 0 MUD WT: HOURS PH O__~.P 3 00 C TB 2 50 C LD 1 50 C LD ACT ACTIVITY DESCRIPTION TEST BOPS, SET WEAR RING, INSTALL MOUSE HOLE & POLLUTION PANS PICK UP 4 1/8 MILL, MUD MTR, 5" SCRAPER AND 24 JTS 2 7/8" DRILL PIPE PICKING UP 2 3~8" TBG TO CLEAN OUT 5" TIE BACK DATE: 7/18/00 DSS: 21 DEPTH: 0 MUD WT: HOURS PH O__P 13 00 C LD 1 00 C DC 6 00 C DC 1 50 C LD 1 00 C CA 1 50 C CA ACT ACTIVITY DESCRIPTION PICKING UP 2 3/8" 8RD TBG TO CLEAN OUT 5" TIE BACK, W / 4 1/8" MILL, MTR & 5" CSG SCRAPER TAG CMT STRINGERS @ 8838', RU TOP DRIVE TO DRLG W / 2 3/8" TBG DRLG CMT & STRINGERS TO 8948', DRLG PLUG & CMT TO 9045' RIH FROM 9045' TO 9568', TAG SAND PLUG DROP BALL TO BY PASS MTR, WASH DN TO 9590' PUMP SWEEP & DRY JOB, POH DATE: 7/19/00 DSS: 22 DEPTH: 0 MUD WT: HOURS PH O__P 8 00 C TR 1 50 C BH 7 00 C TR 0 50 C PT 1 00 c CA 3 50 C CA 2 50 C TR ACT ACTIVITY DESCRIPTION PUMP DRY JOB, POH W 4 1/8" MILL, MTR & 5" CSG SCRAPER, STAND BACK2 3/8 8RD TBG PU OVER SHOT FOR F-LATCH RIH W OVER SHOT, 24 JTS 2 7/8" DP & 2 3/8" 8RD TBG TO 9580' BREAK CIRC, TEST CSG TO 3000 PSI W / 8 6 FIW (GOOD TEST) CIRC DN AND TAG @ 9609', TBG STRAP, WORK PIPE, ATTEMPT TO PULL F LATCH - CROSS OVER FROM 2 3/8" 8RD TO 3 1/2" IF IN TOP DRIVE PARTED WORK PIPE, F LATCH APPEARED TO COME FREE POH, STANDING TBG & DP IN DERRICK DATE: 7/20/00 DSS: 23 DEPTH: 0 MUD WT: HOURS PH O._~P 5 00 C TR 0 50 C BH 3 50 C SR 1 50 C LD 2 00 C SR 7 50 C LD 1 50 C LD 1 00 C CA 1 50 C TR ACT ACTIVITY DESCRIPTION POH, STAND 2 3/8" TBG BACK IN DERRICK, LD 24 JTS 2 7/8" DRLG PIPE LD F LATCH & BAKER OVER SHOT SERVICE RIG, CHANGE PINS ON DEAD LINE ANCHOR P/U BAKER SEAL ASSY, ONE JT 2 3/8" TBG X-NIPPLE, RIH W / 2 3/8" TBG REPAIR DYNAMATIC & SERVICE, HELP ELECT, CLEAN & TIGHTEN CONN ON DRAW WKS CIRCUIT PANEL RIH W / 2 3/8" 8RD TBG ATTEMPT TO STING INTO SEAL BORE, ONLY ABLE TO ENTER ONE SEAL SUB (18") CIR 20 BBL HI VIS SWEEP POH STANDING TBG IN DERRICK Page 8 Copyright © 1993-98 by Epoch Wells~te Services, Inc All nghts reserved Today's Date 814100 WELL NAME. MGS A # 33-14 RIG NAME: XTO PLATFORM A FIELD NAME: MIDDLE GROUND SHOALS EVENT No.: 1 AFE No.: 2000169 WELL ID No.: MGS A # 33-14 APl No.: 50-733- EVENT DESC.: REPAIR TUBING & TREE FAILURE AND P DATE: 7/21/00 DSS: 24 DEPTH: 0 MUD WT: HOURS PH O._.~P 6 00 C TR 2 00 C TR 1 50 C SL 3 50 C TR 1 00 C CA 1 50 C CA 5 50 C TR 0 50 C BH 2 50 C TR ACT ACTIVITY DESCRIPTION POH - STANDING BACK 2 3/8 8RD TBG IN DERRICK LD BAKER SEAL ASSY - P/U 2 1/16" STINGER (15 70') - RIH SLIP & CUT DRILL LINE RIH W/2 3/8 TBG MU TOP DRIVE TO 2 3/8 TBG - BRK CIR @ 9584' -TAG TOP OF PACKER AT 9610' - CIRC INTO TOP OF PKR 16' WITH LITTLE IF ANY RESRICTION PUMP 20 BBL HI VIS SWEEP POH - STANDING BACK 2 3/8 8RD TBG IN DERRICK LD 2 1/16" STINGER - P/U BAKER SEAL ASSY - 1 JT 2 3/8" 4 7# NS0 8RD EUE ABMOD - X-NIPPLE RIH W/2 3/8" 4 7# N80 8RD EUE ABMOD TBG DATE: 7/22/00 DSS: 25 DEPTH: 0 MUD WT: HOURS PH O__~_P AC.T 3 00 C TR 0 50 C LD 2 50 C CA 1 00 C LD 0 5O C TC 4 50 C NU 1 00 C NT 1 50 C CA 3 50 C MD ACTIVITY DESCRIPTION TIH W / BAKER SEAL ASSY(15'), 1JT 2 3/8" 4 7# N80 8RD EUE ABMOD TBG, X-NIPPLE 1 875 ID ,286 JTS 2 3/8" 4 7# N-80 EUE ABMOD TBG, X-NIPPLE 1 875 ID, 9 JTS 2 3/8" 4 7# N80 8RD EUE ABMOD TBG, 7 1/16 BY 2 3/8 TBG HANGER SPACE OUT TBG & MAKE UP 7 1/16 BY 2 3/8 TBG HANGER RIG UP & DISPLACE TBG ANNULUS W / 120 BBLS FIW & EC 1124A NALCO PKR FLUID DRAIN STACK, LAND TBG HANGER TEST TBG ANNULUS TO 2000 PSI (GOOD TEST) SET BPV, NIPPLE DOWN BOP'S NIPPLE UP & TEST TREE TO 5000 PSI R/U TO TREE, PUMP DN TBG, SHEAR PLUG IN TAIL PIPE AT 4000 PSI RIG UP AND BACK FLOW WELL TO PROD, PREPARE TO RELEASE RIG RELEASE RIG FROM A-33-24 TO MOVE TO A-13-12RD @ 2400 HRS ON 7/21/2000 TURN TO HGT PRODUCTION NOTE WELL HAD 1900 PSI AFTER SHEARING OUT PLUG - BACK FLOWED WELL FOR 24HRS AT 150BPD 200PSI- SHUT WELL IN FOR 8HRS PRESSURE BUILT BACK TO 1600PSI SENT SAMPLE TO O/S FOR CHECK Page 9 Copyright © 1993-98 by Epoch Wells~te Services, Inc. All rights reserved ~1-21-00 05:19P Shell Platfom A ) 907 7'76 2522 P.O1 O~.Co. - RF. CEIVED JUL 24 ¢ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS I Type of Request Abandon ~ Suspendj Operabon shutdown~ Re-enter suspended well .~ After casing ~ Repmr well ~ Plugging T~me extension ~ Sbmulate~ Change approved program ~ Pull tubing /% Vanance ~ Perforate ~ Other 2 Name of Operator Cross Timbers Operatinq Company 3 Address 210 PARK AVE. SUITE 2350 OKLA. 4 Location of well at surface CITY, OK. 73102 Type of Well Development Exploratory Strabgraph~c Service X "A", Leg 4, Cond.30 ¢ 1561'N& 385'W fromSE corn. Sec. 11,T8N,R13W,SM 6 Datum elevabon(DForKB) 116' KB 7 Umt or Property name Hiddle Ground Shoal 8 Well number A33-14 At top of productive ~nterval 9061~3008' 5 & 1417'14 from NE corner of Sec. 14, T8N,R1314,S.M. At effective depth At total depth 10555'~3527'5 & 1934'14 from NE corner ,Sec. 14,T8N,R1314,S.M. 9 Permit number 10 AP~ number so- 733-20057-00 11 F~eld/Pool MGS/"G" Pool feet 12 Present well condition summary Total depth measured true vertical Effecbve depth measured true vertical 10,555' feet Plugs(measured) 8816' feet 10432' feet Junk(measured) 8705' feet Casing Length Structural Conductor Surface 1,871' Intermediate10,531' Production Liner 1476' Perforahon depth S~ze Cemented 10-3/4",40..5~,J-55 1500 sx "G" 7",23-29~,N-80 1100 sx "G" 5", 18~, N- 80, BUT measured 9,715' - 10,419' true vertical 150 sx "G" 8,073'-8,693' Tubing (size, grade, and measured depth) 3-1/2", 9.2#, N-80 BUl-rRESS to 8,949' Packers and SSSV (~pe and measured depth) TIW Packer @ 8,970' ORIGINAL Measured depth True vertical depth 0'-1,871' 0'-1,739' 0'-10531' 0'-8795' 8956'-10,432' 7438'-8705' RECEIVED APR 04 000 Alaska 0ii & Gas Cons. Commission Anchorage 13 Attachments Description summary of proposal Detaded operahons program X BOP sketch 14 Estimated date for commenmng operation 15 Status of well classification as 04/22/2000 16 If proposal was verbally approved Od Gas Name of approver /.-) Date approved Service INJECTOR 17 I h~ce~11~t~~.o?g ,s ~.~e and correct to the best of my knowledge S~gned~:::;¢~ 4r~' ~ T~tle Sr. Engineering Tech Suspended __ Date 04/03/2000 Cond~bons of approval Plug ~ntegnty__ BOP Test Mechanmal IntegntyTest / FOR COMMISSION USE ONLY Notify Commission so representabve may w~tness f-"' Location clearance Subsequent form required 10- ~'[OLlt Commissioner ORIGINAL SIGNED BY Robert N. Christenson Approved by order of the Commission Date Form 10-403 Rev 06/15/88 SUBMIT IN TRIPLICATE CROSS TIMBERS OPERATING COMPANY MGS A33-14 COOK INLET, ALASKA WELL DATA SURFACE CASING: PRODUCTION CASING: LINER: TUBING: PERFORATIONS: OBJECTIVE: I0 3/4" 40.5# J55. Set ~ 1871'. Cmt w/1975 sx. 7" 23, 26, 29# N80. Set at 10531'. Cmt w/1100 sx. 5" 18 # N80. TOL ~ 8955'. Set ~ 10432'. Cmt w/150. 3 1/2" 9.2# N80 Butt ~ 8949'. BEHIND LINER BEHIND LINER BEHIND LINER BEHIND LINER BEHIND LINER GN-GO 9061-9085' GR-GS 9435-9451' GR-GS 9456-9472' HC-HD 9715-9804' HE-HF 9860-9888' HI-HK 9954-9995' HK-HN 10060-10162' HN-HR 10162-10239', 10260-10302' HR-HZ 10328-10419' Repair Tubing, Possible Casing Leak and Tree leak Problem: Plan: Note: . HIT/Tree failure/possible HIC Set inflatable BP & POOH w/tbg Pull Inflatable BP Run and Set Bkr pkr on WL w/plug in place Loc and sqz csg leak Run 5" csg to surface if necessary Run new 2 3/8" tbg Replace wellhead/tree SITP 1800 psi. This well would flow 10 gpm when the SITP built to 2600 psi. H2S is 350 ppm. Ail workover fluids to contain H2S scavenger. Have mud and weight materials on location during workover operations. RU SL. Test lubricator. Pull plug in X nipple ~ 321 '. RD SL. Backflow well for 2 weeks prior to RU CTU. MIRU Dowell CT unit. RIH w/2 %" mill, under-reamer (for 5"18# csg) and motor on 1%" CT. Clean out to PBTD +10432'. Circ well w/FIW. POOH. TIH w/Jet Blaster tool and 1%" CT to 9600'MD. Jet csg using Jet Blaster tool and sterling beads from 9600 to 9700'MD. POOH. RIH w/2 W' x 5" Bkr inflatable BP (differential pressure rating of 4800 psi) on 1%" CT. Set inflatable BP +9650' MD. Bleed off wellhead press. Observe well for flow. If no flow, spot 20' of sand on BP (10.7 ppf, 214# of sd) and POOH. If well flows, release BP and POOH. Run backup plug. If well still flows, release BP and POOH. TIH w/ CT and kill weight mud. Note: Inflatable BP must be capable of running thru 2.75" ID nipple, setting in 5". RECEIVED APR 04 tO00 Alaska Oil & Gas Co~s. Commissio~ Anchorage 'CROSS TIMBERS OP(* TING COMPANY ( MGS A33-14 COOK INLET, ALASKA REPAIR TUBING LEAK, POSSIBLE CASING LEAK AND TREE ND tree. Send tree to shore for repair or replacement. NU BOP's and test. PU out of seals and circ well w/H2S scavenger. POOH w/3 ½" 9.2/t N80 Buttress tbg. LD while POOH. Send tbg to shore for inspection. Check all tbg for NORM per OIL 1.00(n)-I (Revised 1/10/92). RU Dowell CT unit. NU BOPs. Test BOPs. TIH w/retrieving tool for Bkr 2 ½" x 5" inflatable BP. Wash sd off BP. Retrieve BP. POOH. RD Dowell. . RU WL w/5000 psi lubricator. Make a GR/JB run to 9650'. Run and set a Bkr DB pkr ~ +_9625' as follows: Top: Item Length Top Btm Bkr DB pkr Size 32-26 3 9625 9628 Seal Bore Extension 15 9628 9643 6' pup jt 6 9643 9649 Otis R topple 1 71" ID 1 9649 965'b 6' pup jt 6i 9650 9656 Otis R topple 1 71" ID 1 9656 965~ 6' pup It 6 9657 9663 VVL Re-entry Guide w/Pump out plug 1 9663 9664 set @ 2000 ps~ RD WL. Expected SITP is as high as 2000 psi. . TIH w/"F" latching plug on 1000' of 2 3/8" DP and 3 ½" DP. Set plug in top of Bkr DB pkr ~ +9625'. RU SL and set equalizing prong in "F" latch. POOH. RD SL. Dump 20' sd on top of plug (10.7 ppf, 214# ofsd). POOH. TIH w/sqz pkr for 5" 18# csg on DP to +_9050' MD and test 5" csg to 1000 psi. If csg tests, POOH w/ pkr. If csg does not test, locate top and btm of leak and a squeeze procedure will follow. TIH w/junk mill and string mill for 7" 29# csg to TOL ~ 8956'. Circ clean. Pump a 40 bbl Xanvis pill. Circ clean. Repeat as necessary. POOH. 10. TIH w/sqz pkr for 7" 23-29# csg on DP. Locate top and btm of possible csg leak. Squeeze procedure will follow. Reverse out excess cmt. POOH. WOC. Drill out sqz and test to 1000 psi. Resqz if necessary. POOH. 11. PU 5.25" polishing mill for TIW PBR ~ 8970' MD (7451' TVD), 6' spacer pup, top dressing mill on 3 DP. Polish PBR and tie back sleeve. POOH. 12. Install B section for 5" csg. RU csg crew. Makeup 5 ¼" seal nipple, orifice collar, 5" 18# L80 STL csg 8956'. Space out. Land liner. Cmt liner and sting into tie back sleeve. Set slips and HO csg. WOC. ND BOP's. Install slip and packoff. Cut offcsg. NU BOP's. RD csg crew. Test 5" packoff to 5000 psi. 13. TIH w/bit and scraper for 5" 18# csg on 2 3/8" 4.7# N80 8R EUE ABMOD to +9600'. Circ well clean using FIW. Test csg to 3000 psi. POOH. 14. TIH w/retrieving tool for "F" latching plug on DP. Circ sd off "F" latch. RU SL and retrieve equalizing prong. RD SL. Retrieve "F" latch. POOH. RECEIVED APR 04 2000 Alaska Oil & Gas Cons. Commission Anchorage CROSS TIMBERS OP( TING COMPANY MGS A33-14 COOK INLET, ALASKA REPAIR TUBING LEAK, POSSIBLE CASING LEAK AND TREE 15. TIH w/seals and 1 jt 2 3/8" 4.7# LB0 8R EUE ABMOD tbg, Otis X nipple 1.875" ID and 2 3/8" 4.7# LB0 8R EUE ABMOD tbg. Locate pkr, PU and reverse out kill fluid w/FIW and 10 gal per 100 bbl of Nalco ECl 120A pkr fluid. Sting into pkr and land tbg. ND BOP's. NU tree. Test tree to 5000 psi. Test annulus to 2000 psi. 16. Press up on tbg to _+4000 psi and pump out plug. Back flow well until clean. (Note: well shuts in at 1800 psi, plug is set at 2000 psi.) 17. Return well to injection. Monitor TP, CP, SurfCsg Press, and injection rate. Notify the AOGCC 48hrs prior to MIT test. MIT well. Doug l~la~shal]- Doug Schultze ~ Date Date Date Date R CEIVED APR 04 000 Alaska ~l & Gas Co~s~ Con~m~ssior Anc~or~e Cross Timbers ~l~rating Company MGS A33-14 WIW Cook Inlet, Alaska Leg 4, Conductor 30 APl No.: Spud: Surf Csg: 10 3/4", 40.5 lb., J55. Set @ 1871' Cmt'd w/1975 sx. Prod Csg: 7", 23~, N80 Buttress. Set @ 0-6500' 7", 26 #, N80. Set ~ 6500'-9900'. 7", 29#, N80. Set @ 9900'-10531' Cmt°d wi 1100 sx. Presenl Com 31etion Liner 5/28/84: 5", 18 lb N80 SFJP. Set @ 8956'-10432'. Cmt w/150 sx G. Circ out excess. No p~pe movement wh~ie cmt. PBTD. 10432' TD: 10555' irs 5/21/99 cdp 9/28/99 KB: ' Water Depth: Tubing 5/29/84:3 1/2", 9.3#, N80 Buttress. Set @ 8949'. Otis "X" Nipple (2.75 ID) @ 321' Otis "X" Nipple (2.75" ID) @ 8949' MD (7434' TVD) TIW Locator @ 8952' MD (7437' TVD) TIW Tie-Back Sleeve @ 8956' MD (7440' TVD) TIW Type S Packer @ 8961' MD (7444' TVD) TIW 20' PBR w/Seals @ 8970' MD (7451' TVD) 1984 Csg leak @ 6150'. Sqz'd w/200 sx G (5/22/84, then ran 5" liner to Isolateold perfs). RF-CEIVED APR 04 000 Alaska 0i~ & Gas Co~s. C.,o~m~ssior Anchorage GN-GO: 9061-9085 (Behind Liner) GR-GS: 9435-9451 (Behind Liner) GR-GS: 9456-9472 (Behind Liner) HC-HD: 9715'-9804° HE-HF: 9860-9888 (Behind Liner) HI-HK: 9954-9995 (Behind Liner) HK-HN: 10060'-10162' HN-HR: 10162'-10239' HN-HR: 10260'-10302' HR-HZ: 10328'-10419' 5/21/84 original perfs sqz°d wi 250 sx G below cmt retainer @ 9593' Cross Timbers O~ --ating Company Proposed Completion MGS A33-14 WIW Cook Inlet, Alaska Leg 4, Conductor 30 APl No.: Spud: Surf Csg: 10 3/4", 40.5 lb., J55. Set @ 1871' Cmt'd w/1975 sx. KB: ' Water Depth: Tbg: 2 3/8" 4 7# N80 8R EUE ABMOD item Length ToD Btm Bkr DB pkr S~ze 32-26 3 9625 9628 Seal Bore Extension 15 9628 9643 6' pup It 6 9643 9649 Otis R topple 1.71" ID 1 9649 9650 6' pup jt 6 9650 9656 Otis R topple 1.71" ID 1 9656 9657 6' pup jt 6 9657 9663 WL Re.entry Guide wi Pumpout plug set @ 2000 psi 1 9663 9664 1984 Csg leak @ 6150'. Sqz'd wi200 sx G (5/22/84, then ran 5" liner to ~solateoid perfs). Prod Csg: 7", 23~, N80 Buttress. Set @ 0-6500' 7", 26 #, N80. Set @ 6500'-9900'. 7", 29~, N80. Set @ 9900'-10531' Crnt'd w/1100 sx. R CEIVED 04 000 Alaska {:)ii & Gas Cons. C0mmissbn And~or~ Proposed Liner: 5" 18# N80 Hydnl 513 from 0-8956'. Cmt'd to surfw/ 800 sx G. Liner 5/28/84: 5", 18 lb N80 SFJP. Set @ 8956'-10432'. Cmt w/150 sx G. Circ out excess. No pIpe movement while cmt. GN-GO: 9061-9085 (Behind Liner) GR-GS: 9435-9451 (Behind Liner) GR-GS: 9456-9472 (Behind Liner) HC-HD: 9715'-9804' HE-HF: 9860-9888 (Behind Liner) HI-HK: 9954-9995 (Behind Liner) HK-HN: 10060'-10162' HN-HR: 10162'-10239' HN-HR' 10260'-10302' HR-HZ: 10328'-10419' PBTD: 10432' TD: 10555' 5/21184 ong~nai perfs sqz'd w/250 sx G below cmt retainer @ 9593' 3 Address ~xP~lratony ------. 4. Location of well at surfa~-e Leg 4,Cond. 30e~61'N&385,W f~om SE cn~ of Sec. At fop of Productive 9061'~008'S&1417,~ fPom NE cn~ of Sec. 14, TSN, R~3W, S.M. At effecbve depth At total 10555'e3527.S & Ig34'H fr~ NE cnr of Sec. 14, TSN, R13~, S.~. ~, Pre~ent well c~d~bon sUmma~ TOtal depth Effective depth Cas,no Structural Conductor surface 3872' Intermediate Production 310531' Liner 1476' Perforabon depth STATE OF ALASKA ( ALASKA OIL AND GAS CONSERVATIO OMMISSION APPLICATION FOR SUNDR fc ___APPROVALS After camng ~ Rel~t well Re-si Change apprOVed Program__... "~11 Plugging.._.._.. Tfme ext ~ub, ng ~ Vartanoe ~ens,on ~'"~te._.~ Stimu~ate.~.~ Of Well Other measured ;[0555 feet Plug~ {measurec0 true vertical 88~[6 feet measured 10432 feet true ~dJCal 8705 feet Junk (measured) Length Cemented 10-3/4", 40. ~, J55 7".23'29~.N-80 measured 5", ~,8i~, N,80 9715' . 10419' 5 lnte~'vals true ve~cal 8073' . 8693' 3-1/2", 9,2#, N-80 Buttress ~ 8949' Tubing (size, graue, and measure~ depth) depth) summary of pruposa~ 13, Altaohments 1000sx llOOsx 150sx oPembOn :. 1999 Proposal was vemel~ aPProved Blair ll Measured depth O' . 1871' O' · 10531' 8~56'. 10432' correct to Shoal 9 Permd number 67'68/94-125 50- 20057.00 ~GS "a" Pool True veri/aal del~th 0' . 173~' O' - 8795' 7438' . 8705' ORIGINAL Detailed Operations program Od Se~vme ~ BOP sketch Suspended Pl 6)/I 13 Conditions of aPproval: Notify Commission so repmsentabve may Wltnee$ Plug integrity ...... BOP Te~t ..._.. Lo~aban ~tearance -----_ Mechanical Inte.onty Test ~ Subsequent form required ORIGINAL SIGNED BY r of the Commission Robert N. Chdstenson Form 1 O- 403 Rev 06/15/80~ -- --" - Date NOV 39 11-19-99 · ID= PII/13 BARRELS INSECTED A33-14 INJECTION PRESSURE ANNULUS PRESSURE 07/01/1999 07/02/1999 07/03/1999 07/04/1999 07/05/1999 07/06/1999; 07/07/1999 07/08/1999 07/09/1999 07/I0/I999 07/11/1999 07/12/1999 07/13/1999 07714/1999 07/15/1999 07316/1999 07717/1999 07/18/1999 07119/1999 07/20/t999 07/21/I999 07/22/1999 07/23/1999 07/24/1999 07/25/1999 07/26/19991 07/27/1999! 07/28/19991 07/29/1999 07/30/1999 07/31/I 999 424 616 572 529 538 551 542 570 587 568 576 572 573 568 565 487 567 549 546 546 549 541 548 546 559 563 556 530 487 463 476 16864 544 3650 3650 3650 3650 3650 3650 3650 3675 3700 3700 3675 3675 3700 3700 3700 3700 3700 3700 3700 3700 37OO 3650 3650 3650 3650 3650 3650 3650 3650 3650 3650 July 1999 Injection July 1999 Average Daily Injection 250 180 190 200 210 200 220 215 200 705 215 205 205 210 210 210 210 210 210 210 210 230 235 23O 23O 220 220 220 250 250 240 RECEIVED 1 9 1999 11-19-99 lO:a5 ID-- 08/01/1999 08/02/1999 08/03/I 999 08/04/1999 08/05/1999 08/06/1999 08/07/1999 08/08/1999 08/09/1999 08/10/1999 0g/l 1/1999 08/12/1999 08/13/1999 08/14/1999 0g/l 5/1999 08/16/1999 08/17/1999 O8/18/1999 08/'19/1999 08/20/1999 08/21/1999 08/22/1999 08/23/1999 08/24/1999 08/25/I 999 08/26/1999 08/27/1999 08/28/1999 08/29/1999 08/30/I999 08/31/1999 BARRELS INJECTED ,, 488 479 472 475 484 486 488 485 492 488 492 493 494 489 495 490 485 492 494 491 500 497 497 499 502 517 509 463 432 581 548 15297 493 A33-14 INJECTION PRESSURE ANNULUS PRESSURE August 1999 August 1999 3650 3650 3650 3650 3650 3650 3650 3650 3650 3650 3650 3650 3650 3650 3650 3650 3650 3650 3650 3650 3650 3650 3650 3650 3650 3650 3650 3650 350O 3650 3650 Injection Average Daily Injection 240 240 250 250 240 245 240 235 230 235 230 240 240 240 240 240 240 230 235 235 235 235 235 230 230 220 22O 220 280 190 20O RECEIVED '0V 1 9 1999 ID-- BAR}LELS INJECTED A33-14 INJECTION PRESSUKE ANNULUS PRESSURE 09/01/1999 09/02/1999 09/03/1999 09/04/1999 09/05/1999 09/06/1999 09/07/1999 09/05/1999 09/09/1999 09/10/1999 09/11/1999 09/12/1999 09/13/1999 09/14/1999 09/15/1999 09/16/1999 09/17/1999 09/t8/1999 09/19/1999 09/20/1999 09/21/1999 09/22/1999 09/23/1999 09/24/1999 09/25/1999 09/26/1999 09/27/1999 09/28/I 999 09/29/1999 09/30/1999 539 548 547 476 489 484 444 53 635 559 558 569 570 560 558 544 550 555 548 553 546 554 564 289 0 0 507 0 0 0 12799 512 365O 200 3650 200 3650 195 3650 215 3625 215 3600 215 3600 220 3525 345 3525 190 3650 190 3650 170 3650 170 3650 170 3650 170 3650 170 3650 170 3650 170 3650 215 3650 215 3650 165 3650 160 3650 155 3650 150 3650 150 3000 340 2500 390 3550 300 2700 2650 2500 2500 2500 2450 September 1999 I~ection September 1999 Average Daily I~e¢tion RECEIVED NOV 1 9 1999 Alaska Oil & was ~oa$. uommis~lon oho_ralte 11-19-99 ¢ Cross Timbers Operating Company ID= November ! 9, 1999 Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Blair: SUB,IECT: APPLICATION FOR SUNDRY APPROVAL 0fORM 10-403) TO SUSPENDfrE~ORA~!Ly ABANDON WELL NO. A33-14. Enclosed in triplicate is the Application for Sundry_ .ApprowL Form I0-403, to suspend/temporarily abandon ,433-14. Cross Timbers' Production Superintendent, Doug Marshall, notified the AOOCC of pressure communication observation between the injection tubing and casing via telephone conversation with you on 09/30/1999. Due to the fact that this well has a suspected casing failure as well as a tubing failure, we immediately shut in the well and have scheduled it to be repaired during our rig program in 2000. A summary, of the daily injection from 07/01/1999 to 09/28/1999 Js attached. If you have any questions, please don't hesitate to call me at (907) 776-2511. Thank you! Sincerely, W A Mille~ Office Manager Attachments RECEIVED t'0V 1 9 1999 HC01 Box aSS. Old W~k Road. Kena~, AK 99611-9704 Onshore phone- (907) 776-2511, O~shore fax: (907) 776-2542 Platform A fax: (907) 776-~522, Platform C fax: (907) 776-2,532 www. crosstimbem.com Shell Westem E&P Inc. 130 Trading Bay, Suite 310 Kenm, Alaska 99611 (907) 283-3096 January 10, 1995 Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: REFERENCE: SUBMITTAL OF REPORT OF SUNDRY WELL OPERATIONS (FORM 10-404) for MIDDLE GROUND SHOAL A33-14 SUNDRY APPROVAL NUMBER 94-125 Enclosed are duplicate copies of the Report of Sundry Well Operations (Form 10404) for Middle Ground Shoal A33-14. A coiled tubing clean-out and xylene/acid treatment were attempted in the "G" Pool on 05/22/94 and 05/23/94. The well was successfully cleaned out with thc coiled tubing to a depth of 10,418 feet, after which a leak was discovered in the coiled tubing. The coiled tubing was rigged down with the idea that the stimulation portion of the operation would be done at a later date. However, it did not ever become a high priority to remm to A33-14 with a coiled tubing unit in 1994. SWEPI has since decided to focus efforts elsewhere and does not plan to do the stimulation work on A33-14 at this time If you have any questions or wish to discuss, please call Alan Foglesong at (907) 283-2509. Sincerely, Alan Foglesong Senior Production Engineer RECEIVED JAN 1 7 1995 Alaska Off & Gas Cons, Commissloa ~ch0ra ~ STATE OF ALASKA '~1 SKA OIL AND GAS CONSERVATION COMIC' 'lION REPOR OF SUNDRY WELL OPERATIONS 1. Operations pedormed: Operation shutdown Pull tubing __ SI]mulate Plugging I Perforate __ Alter casingI Repair well I Other X 2. Name of Operator Shell Western E&P Inc. 3. Address 130 Trading Bay, Suite 310 Kenai, AK 99611 5. Type ot Well: Development Explorato~j Stratigraphic Serv~.,e X 4. Location of well at surface At top of productive interval Platform "A", Leg 4, Conductor 30 @ 1561'N & 385~/from SE corner of Section 11, T8N, R13W, S.M. 9061' @ 3008'S & 1417'W from NE corner of Section 14, T8N, R13W, S.M. At effective depth At total depth 10555' @ 3527'S & 1934'W from NE corner of Section 14, T8N, R13W, S.M. 6. Datum elevation (DF or KB) 116' KB feet 7. Unit or Property name Middle Ground Shoal 8. Well Number A33-14 9. Permit number/approval number 67-68/94-125 10. APl number 50-733-20057-00 11. Field/Pool MGS "G" Pool 12. Present well condition summary Total depth: measured Effective depth: Casing Structural Conductor Sudace Intermediate Production Liner 10555 feet true vertical 8816 feet measured 10432 feet true vertical 8705 feet Length Size Plugs (measured) Junk (measured) Cemented 1871' 10-3/4", 40.5#, J-55 BTC 1500 sx 10531' 7", 23-29#, N-80 Buttress 1100 sx 1476' 5", 18~, N-80 Buttress 150 sx ORIGINAL Measured depth True vertical depth O' - 1871' O' - 1739' 0' - 10531' 0' - 8795' 8956' - 10432' 7438' - 8705' Perforation depth: measured 9715' - 10419' 5 Intervals true vertical 8073' - 8693' Tubing (size, grade, and measured depth) 3-1/2", 9.2#, N-80 Buttress @ 8949' Packers and SSSV (type and measured depth) TIW PBR set @ 8970' Rrr..C£1V£g JAN 1 7 1995 13. Stimulation or cement squeeze summary See attachment Intervals treated (measured) None - see attachment Treatment description including volumes used and final pressure 0il & Gas Cons. Commission Anchom" 14. Prior to well operation Subsequent to operation OiI-Bbl Reoresentative Daily Averaae Production or Injection Date, Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 5O 18 3750 518 / 18 3650 15. Attachments: Copies of Logs and Surveys run Daily Report of Well Operations X 17. I hereby certity that the foregmng ~s true an Form 10-404 Rev 06/15/88 6. Status of well classification as: Oil__ Gas __ Suspended I correct to the best ot my Knowledge TRle Senior Production Engineer Service Water Injector Date C>///D/~,)'-"' SUBMIT IN DUPLICATE STIMULATION OR CEMENT SQUEEZE SUMMARY A33-14 A co~lcd tubing clean-out and xylene/ac~d treat were attempted in the "G" Pool on A33-14. The well was successfully cleaned out with the coded tubing to a depth of 10418', encountering bridges at 10162', 10212', 10247', and 10334' At this point, the coiled tubing was found to have a leak. The coiled tubing was rigged down with the idea that the remainder of the job would be done at a later date with different coiled tubing. However, it did not ever become a high priority to return to A33-14 with another coiled tubing unit to stimulate the well. (The coiled tubing clean-out appeared to improve the injectivity of the well, though probably not to the degree it would have if done in conjunction with a stimulation treatment.) It has since been decided that the well will not be stimulated at this time. Rf. Cf.l¥£O JAN 1 7 '1995 Oil & Gas Cons. Commission Anchora ~ c./files/sundry/a3314cta, sun * TIME AND S~ OF OPfRATION$: *8:00-24:00 RIG UP COIL TUBING AND HALLIBURTON. * * * * . * * REC£1¥£D Gas Cons. Commission * "S~ OF D&ILY COST" * * SWEPI SUPERVISION & lABOR: $700.00 * * CONTRACT * i..COIL TUBING $6,842.00 A..SWE?Z PUR~D SUPPLIE ~0.00 * * B..HALLI~ $1,380.00 B..MI DRILLING FLUIDS ~O.OO * C..CRaNi{ CT,{~ S924.00 C.. ~0.00 * * , D.. W]{LDIER.. H~LP]ER $250. O0 D.. $0_ O0 * * g.. PEAK * F.. $0.00 F.. SD.O0 * G.. $0.00 C;.. $0.00 * H.. $0.00 H,. $0.00 * * I.. $0.00 I.. $0.00 * * J.. $0.00 L.. $0.00 * * K.. $0.00 TOTAL t'~I~%t.,S $0.00 * * [,.. $0.00 * * TOTAL CONTRAC'~T SERVICES $10,246.00 $0.00 * * :!~. O0 * * ; TRaNSI:gRTATI~ * TR~St:'O~IO~: AIL OTE~:R $0.00 $0.00 * , TOTAL P. 01 b~-~-1~4 Id~:bKFiFm k~dFI ~hell I~lat+orm H ~U R~ ~hhl~ ~.~ .... ~ ................... A~H: $75, ~0 ~2~, 2~6.50 ........ ,_, ..... ,-,-.-,-,-,-,. * ~I ~: .... 0 ~l ~P: .... 0 DAYS t ~YS f~TED: 2 * ~: NO 'AUUID~ ~~ED F~ID ~f: FIW ~I~: ~ SPI~: ~ SPI~ ~~8D ~ ~ ~G ~~: ~F: ................................ ,~ .................................................. * TI~ ~D S~Y OF O~TI~: *10:00-11:00 ~ '~~ ~ING ~ ~IL ~BING JOB. INC~D~ IN ~F~ ~IN~ W~:~ .11:00-17:00 RIH WI~ ~. ~ ~T~ 1/4 M~ AT 820 ~I. AT 9~00' ~ 1 ~ AT 2~ .~I. ~D BRI~ AT 10162, 10212, 10247, 10~. ~ P~~ AT ~ OF ~ BRI~S. TA~gD ~ AT 10418. ~ *~D 5 BBL ~S PI~ ~~D BY FIW AT 1 BBL P~ AT 2~ ~I. *aT ~V a PIN HO~ WAS ~D IN ~ ~IL ~INO. · 17:00-24:00 RIO DOWN COIl, TUBING. , · RECEIVED ·· JAN 1 ? 1995 ,AT 22:00 WI~LL WAS RBTURNgD TO ItUgCTION. TH~ k~LL HAS DEFINATI~LY RKSPONI)IiD TO TH{ * ~ CLEAI~ OUT. AT 5:00AM THE W~.LL WAS STILL INJECTINO AT I RATK OF 1500 BBLS P/D. * , , * , * · "SUII~Y OF II~IL¥ COST" , · SWKPI SUPS!SION & LABOR: $700.00 * · C~CT SIiR¥ICES' liAT~RIALS: * · A..~IL ~ING ~,446.~ A..S~PI ~~KD SUPPLIE ~.~ * · B..~IBU~N ~10,800.00 B..HI ~I~INO F~I~ $100.~ * · U..~g ~ ~1,4~.~ ~.. ~.~ * · D.. ~~, .~~ ~. O0 D.. ~. ~ · · ~.. P~ ~ ~50. O0 g.. · F.. ~0.~ F.. ~.~ · O.. ~.00 G.. ~.~ · H.. ~.~ H.. ~.~ · I.. ' $0.00 I.. ~.~ * · d.. $0.00 L.. ~.~ * · . $0.00 · ~AL ~~ SERVICES ~,496.50 ~.00 · ~S~TI~: ~ ~ ~.~ ~0.00 * TOTIqL P. 02 y. Shell Western E&P Inc. An affiliate of Shell Oil Company 601 West Fifth Avenue Suite ~0 Anchorage AK 99501 July 7, 1994 Alaska Oil and Gas Conservation Commission ATTN- Blair Wondzell 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT' SUBMISSION OF FORM 10-403 APPLICATION FOR SUNDRY APPROVAL TO CONTINUE INJECTION OPERATIONS ON MGS A33-14 Enclosed in triplicate is the Application For Sundry Approval to continue injection operations on Middle Ground Shoal Well No. A33-14. It is my understanding that a follow-up Form 10-404 is not required for this operation. If you have any questions or wish to discuss, please call me at (907) 263- 9646. Sincerely, Paul Huckabee Staff Production Engineer Western Asset, Alaska Engineering Enclosures RECEIVED JUL 1 2 1994 Alaska Oil & Gas Cons. Commission Andmrage ' A~ STATE OF ALASKA ~..,ON ..~KA OIL AND GAS CONSERVATION COMM APPLICATION FOR SUNDRY APPROVALS 1 Type of Request: Abandon __ Suspendm Operatmn shutdown Re-enter suspended well Alter cas,ng Roper Well Plugging __ Time extension Stimulate Change approved program __ Pull tubing Varance Perforate m Other X 5. lype bt Well: 6. Datum elevation (DF or KB/ 2. Name of Operator Shell Western E&P Inc. Development 116' KB feet 3. Address 601 West 5th Avenue, Suite 920 Exploratory 7. Unit or Property name Anchorage, AK 99501 Stratigraph~c __ Middle Ground Shoal Sew,ce X 8. Well number 4. Location of well at Platform "A", Leg 4, Conductor 30 @ 1561'N & 385'W from SE A33-14 sudace comer of Section 11, TSN, R13W, S.M. 9. Permit number At top of productive 9061' @ 3008'S & 1417'W from N.E. comer of Section 14, TSN, 67-68 interval R13W, S.M. 10. APl number At effective depth 50-733-20057-00 10555' @ 3527'S & 1934'W from N.E. comer of Section 14, T8N, 11. Field/Pool At total depth R13W, S.M. MGS "G" Pool 12. Present well condition summary Total depth: measured 10555 feet Plugs(measured) 0R'~ true vertical 8816 feet ~ ~ Effective depth: measured 10432 feet Junk (measured) true vertical 8705 feet Casing Length Size Cemented Measured depth True vertical depth Structural Conductor Sudace 1871' 10-3/4", 40.5#, J-55, BTC 1500 sx 0' - 1871' 0' - 1739' Intermediate Production 10531' 7", 23-29#, N-80 Buttress 1100 sx 0' - 10531' 0' - 8795' Liner 1476' 5", 18~, N-80 Buttress 150 sx 8956' - 10432' 7438' - 8705' Pedoration depth: measured 9715'-10419' 5 Intervals R E ¢ E IV E D true vertical 8073'- s693' JUL 3 2 1994 Tubing (s~ze, grade, and measured depth) 3-1/2", 9.2#, N-80 Buttress @ 8949' Ataska 0il & Gas Cons. Commission Packers and SSSV (type and measured depth) TIW PBR set @ 8970' Anchorage 13. Attachments Description summary of proposal ~ Detaded operations program B BOP sketch 14. Estimated date for commencing operation 15. Status of well classification as: Oil Gas Suspended 16. If proposal was verbally approved B ~ Service Injector Name of approver Date approved 17. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ("'.._iD~J2 ,.[ ~ Title Staff Production Engineer Date '7 [o · ~, FOR COMMISSION USE ONLY Condihons of approval: Notify Commission so representative may witness I Approval No. Plug integnty_ BOP Test Location clearance ] C:), z/'-/~?~/ Mechanical Integrity Test__ --Subsequent form requi"~d 10- ---/' ·/~--' Approved by order of the Commission,~~.~~::~ ~ Commissioner Date Form 10-403 Rev 06/15/88 SUBMIT IN TRIPLICATE DESCRIPTION SUMMARY OF PROPOSAL MIDDLE GROUND SHOAL A33-14 Further to our discussion with Blair Wondzell on June 14, 1994, we have tested annular pressure integrity on Middle Ground Shoal (MGS) A33-14. The results of the test are as follows' Test Pressure 30 min Fall-Off Pressure 500 psi 500 psi 1000 ps i 900 ps i 1500 psi 1240 psi Indication is that the annulus has pressure integrity up to 1000 psi, but has a small leak above 1000 psi. Normal operating pressure on this well is less than 200 psi on the annulus and 3700 psi on the tubing. These pressures verify tubing integrity and casing integrity under normal operating conditions. Verification of tubing integrity will be confirmed by daily pressure monitoring and monthly AOGCC reporting via form 10-406. A significant unexplained increase in injection rate or annulus pressure will be reported to the AOGCC immediately. We request permission to continue operation of MGS A33-14. RECEIVED JUL 1 2 1994 Oil & llas Cons. Commission June !7, lg94 ( Shell Western E&P Inc. P.0:1 601 Weet Fdth Avenue Alaska Oil and Gas Conservation Commission ATTN: Blair Wondzell 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: MIDDLE GROUND SHOAL A33-14 MIT UPDATE Further to our discussion on June 14, 1994, we have tested annulet pressure integrity on Middle Ground Shoal (MGS) A33-14. The results of the test are as follows: Test Pressure 30 min Fall-Off Pressure 500 psi 500 psi 1000 ps i 900 ps i 1500 psi 1240 psi Indication is that the annulus has pressure integrity up to lO00 psi, but has a small leak above 1000 psi.J'Normal operating pressure on this well ~less than 200 psi on the annulu~ and 3700 psi on the tubing. These ~pressures verify tubing integrity and casing integrity under normal operating conditions. Verification of tubing integrity will be confirmed by daily pressure monitoring and monthly AO$CC reporting via form 10-406. A significant unexplained increase in injection rate or annulus pressure will be reported to the AOGCC immediately. We request permission to continue operation of MGS A33-I4. If you have any questions or wish to discuss further, please call me at (907) 263-9646. P. T. Huckabee Staff Production Engineer RECEIVED JUN 30 1994 Anchorage TOTRL P.01 May l6, 1994 Shell Western E&P In~~ 601 West F,fth Avenue · State 800 Anchorage, Alaska 99501 Alaska Oil and Gas Conservation Commission 3 001 Porcupine Drive Anchorage, AK 99501 SUBJECT SUBMITTAL OF APPLICATION FOR SUNDRY APPROVALS (FORM 10-403) for MIDDLE GROUND SHOAL A33-14 Enclosed in triplicate is the Application for Sundry Approval to clean out and acid treat MGS A33-14 Operations are expected to begin May 19, 1994. If you have any questions or wish to discuss, please call Paul Huckabee at (907) 263-9646 Sincerely, Paul Huckabee Staff Production Engineer RECEIVED MAY 1 7 1994 Alaska 0~i & Gas Cons. Commission Anchorage '~' STATE OF ALASKA COMM~,ON A~ ..~KA OIL AND GAS CONSERVATION APPLICATION FOR SUNDRY APPROVALS ~.'Type of Request: Abandon __ Suspend__ Operation shutdown __ Re-enter suspended Well Alter camng __ Roper Well__ Plugging __ Time extension __ Stimulate __X Change approved program __ Pull tubing Variance __ Perforate ~ Other 5. l-"~pe ct Well: 6. Datum elevation (~-~'o'~ KB1 2. Name of Operator Shell Weetem E&P Inc. Development 116' KB feet Exploratory ~7. Unit or Property name- 3. Address 601 West 5th Avenue, Suite 920 Anchorage, AK 99.501 Straligraph,= Middle Ground Shcal servme X 8. Well number 4. Location of well at Platform "A", Leg 4, Conductor 30 @ 1501'N & 38~'W from SE A33-14 sudace comer of Section 11, TSN, R13W, S.M. 9. Permit number At top of productive 9061' @ 3008'S & 1417'W from N.E. comer of Section 14, T8N, 67-6&'. ~nterval R13W, S.M. 10. APl number - At effective depth 50-733-20057-00 ,., 10555' @ 3527'S & 1934'W from N.E. comer of Section 14, T8N, 11. Field/Pool At total depth R13W, S.M. MGS "G" Pool i2. Present well condition summary Total depth: measured 10555 feet Plugs (measured) true vertical 8816 feet Effective depth: measured 10432 feet Junk (measured) true vertical 8705 feet Casing Length Size Cemented Measured depth True vertical depth Structural Conductor Sudace 1871' 10-3/4", 40.5~, J-55, BTC 1500 ox O' - 1871' 0'- 1739' Intermediate Production 10531' 7", 23-29~, N-80 Buttress 1100 ox O* - 10531' O' - 8795' Liner 1476' 5", 18~, N-80 Buttre~ 150 ex 8950' - 10432' 74,38'. 870S' Perforation depth: measured 9715' - 10419' 5 Intervals Tubing (size, grade, and measured depth) 3-1/2", 9.2#, N-8O Buttre~o @ 8949' MAY ~ 7 ~994 Packers and SSSV (type and measured depth) TIW PBR set @ 8970' At~ska Uti & Gas Cons, Commission Anchorage '13. Attachments Descnption summary of proposal X Detailed operations program __ BOP sketch 15. Status of well classification as: 14. Estimated date for commencing operation /~ Oil Gas Suspended 16. If proposal was verbally approved Service Injector Name of approver Date approved 17. I hereby certify that th.e forgoing is true and correct to the best of my knowledge _ Signed ~....~ ~~ Title Staff Production Engineer Date ~/ (3- ~ ~'4. FOR COMMISSION USE ONLY Plug integrity. BOP Testj Location clearance__ Mechanical ]n~'~grity Test__ Subsequent form required 10- /y 0 L{ ORIGINAL SIGNED BY Approved by order of the Commission RIJS~;ELI. Form 10-403 Rev 06/15/88 Approved Copy Returned SUBMIT IN TI: .ICATE MIDDLE GROUND SHOAL HELL No. A33-14 COZLED TUBING CLEAN OUT & XYLENE/ACID TREAT PRESENT STATUS: Active Injection Well Last Test 05/10/94 49 BWPD @ 3650 psi OBJECTIVES: 1) CTU Clean-Out with PDM and mill. 2) Acid Treat HEMLOCK VIA 7.5% HC1 soak/jet wash/squeeze. 3} Dispose of contaminated return fluid. NOTES: - 3-1/2" 9.2# N-80 BTC tubing, EOT @ 8949' MD - 5" 18# N-80 liner below EOT via tieback, - PBTD = 10432' -Minimum restriction- 2.750" ID, Otis "X" nipples @ 8949' & 321' - CTU acid wash out to 10325' 6/29/88 (copy of clean out attached) - Scale filled tagged as follows: @ 10078' via slickline on 3/28/94 @ 9960' via perf guns on 3/30/94 @ 4570' via perf guns on 4/01/94 @ 1340' via slickline on 4/24/94 - Scale analysis indicates primary fill is iron-sulfide. RECOHNENDED PROCEDURE: (Refer to Attached COMPLETION EQUIPMENT DETAIL SHEET for mechanical equipment details) 1. Prior to scheduled CTU rig-up: a) Review all data files for information on junk in hole, fill indications, tubing blockages, and tubing ID restrictions. The following responsibilities are identified. - Anchorage Well Files - Production Engineering - Platform Well Files - SWEPI CTU Supervisor - Wireline Log Book - Wireline Operator b) Test mechanical integrity of all critical components (ie., swab valve, wing valve, tubing spool valve ect.). Pressure test all critical components to 5000 psi. Repair or replace defective components. 2. Hold safety meeting with all service companies and platform personnel to discuss the proposed operations. Emphasize safety concerns with the chemicals to be used and with H2S during acidizing operations. NOTE: H2S concentrations greater than 1000 ppm are expected in spent acid returns during MGS injection well acid treatments. 3. The SWEPI CTU Supervisor should ensure all equipment to be run in the hole is calipered for both ID and OD, and that a complete dimensional drawing of each component is on file. RECEIVED A3314AT. PRG Page 1 v 1 7 1994 Gas Cons. Commission Anchorage MIDDLE GROUND SHOAL No. A33-14 COZLED TUBING CLEAN OUT & XYLENE/AC]D TREATMENT 4. Ensure crown valve is closed. RU CTU with 1-1/2" coiled tubing and CTU assist pump. Install double check valves and hydraulic disconnect on coiled tubing. RU BOPE and flow "T". (NOTE: Equip CTU BOPE stack with blind rams, shear rams, and pipe rams.) Test CTU BOPE and coiled tubing to 5000 psi against swab valve and CTU stripped rubbers. Bleed coiled tubing pressure to negative test the double check valves. 5. RU Halliburton with 100+ bbls pumpable volume of 7-1/2% HC1 acid. Include the following additives in the acid. - 0.5'~HAI-85 Corrosion Inhibitor, - 0.2% LoSurf-300 Non-Emulsifying Agent/Surfactant, - 20#/1000 gal FERCHECK-A iron chelating agent. Ensure all hazardous materials are properly manifested in accordance with Oepartment of Transportation Regulations. 6. RU valve manifold so the CTU assist pump can quickly access the 7-1/2% HC1 acid and FIW independently. Filter all fluids pumped downhole through 3 micron filters. 7. RU instrumentation to monitor injection rate, coiled tubing injection pressure, coiled tubing (CT) x production tubing (tbg) annulus pressure, and tbg x casing (csg) annulus pressure. 8. RU 250 bbl Production Testing Services tank(s) and ensure surface handling equipment is installed to safely and efficiently handle return acid and H2S for either disposal into A41-11 or treatment and transfer to Production (see Attachment No. 2). CLEAN OUT TO PBTD 9. RIH with 2.5" wavy bottom mill, 2-1/16" Positive Displacement Motor (PDM), double check valves, and hydraulic disconnect sub on 1-1/2" coiled tubing. Clean out scale from tubing and any fill across perfs to PBTD @ 10432'. NOTE: If hard scale is encountered within the HR-HZ perforation interval, do not try to clean out any deeper without approval of Manager Alaska Operations. Top of HR-HZ perf at 10328', bottom perf at 10419'. 10. Mix a 5+ polymer gel pill in FIW with 3#/bbl XANVIS polymer. At the maximum rate possible without exceeding pressure limitations or PDM constraints, pump a 5+ bbl XANVIS polymer pill sweep to clean up any debris from the wellbore. POOH with PDM & mill. A3314AT. PRG Page 2 RECEIVED MAY 1 ? 1994 A~aska Oil & Gas Cons. Commissm~ Anchorage MIDDLE GROUND SHOAL No. A33-14 COILED TUBING CLEAN OUT & XYLENE/ACID TREATMENT ACID SOAK TUBING SCALE NOTE: Cci led tubing length = 13300' 1-1/2" coiled tubing capacity = (1.597 bbls/lO00') * 13300' = 21.24 bbls CT x 5" 18# csg (HZ - HC) = (10419' - 9715') * 0.015574 bbl/ft = 11.0 bbl CT x Wellbore annulus capacity = from bottom perf to EOT 0.015574 bbl/ft * (10419' - 8970') from EOT to surface + 0.006510 bbl/ft * 8970' -- 22.6 + 58.4 bbl -- 81.0 bbls 11. RIH with swirl type jet nozzle and double check valves on 1-1/2" coiled tubing to the bottom perforation @ 10419' or depth of clean-out if shallower. Pump/spot 32.2 bbls 7-1/2" HCL acid to displace 11 bbls acid out of the end of coiled tubing (EOCT) across perforations. 12. Let acid soak for a minimum of 30 minutes. While acid is soaking, reel coil so that the end of coiled tubing (EOCT) is at the top perforation at 9715' in preparation for jet wash. JET WASH PERFORATIONS 13. With the EOCT (jet wash nozzle) at the top perforation (9715'), pump / circulate at 1 BPM the following volumes of 7-1/2% HC1 while reeling coiled tubing down across the perforation intervals at the indicated reel rate (feet/min). NOTE: These volumes are intended to jet wash perforations from 9715' to the bottom HR-HZ perforation at 10419'. Any additional scale areas identified in the 5" liner section should also be jet washed with 7.5% HC1 acid. DEPTH INTERVAL WASH FEET CT REEL RATE WASH VOLUME CUMULATIVE WASH VOLUME 9705' - 9805' 100' 20 ft/min 5.0 bbls 5.0 bbls 9805' - 10060' 255' 40 ft/min 6.5 bbls 11.5 bbls 10060 - 10420' 360' 20 ft/min 18.0 bbls 29.5 bbls Other Intervals? ' - ' ' 20 ft/min bbls bbls ' - ' ' 20 ft/min bbls A3314AT. PRG Page 3 bbls RECEIVED MAY 1 7 1994 Alaska O~l & Gas Cons. Commission Anchorage MIDDL~ GROUND SHOAL No. A33-14 COILED TUBING CL. EAN OUT & XYLENE/ACID TREATMENT 14. Locate the EOCT at the depth of clean out. Mix a 5+ bbl polymer gel pill in FIW with 2.5#/bbl XANVIS polymer. At the maximum rate possible (do not exceed 5000 psi CT pressure), pump/circulate a 5+ bbl XANVIS polymer pill sweep to clean up any debris from the wellbore. Displace/circulate with a minimum of 125 bbls FIW to clear contaminated fluid from the coiled tubing and the wellbore. Divert all acid returns to the surge vessel for disposal. Monitor return fluid for H2S and treat with MI SSII as needed. ACID SQUEEZE STIMULATION 15. Locate EOCT at the bottom HR-HZ perf @ 10419'. Spot circulate 32 bbls 7-1/2% HCL (with above additives) to the EOCT and across the perforation interval. Close coiled tubing annulus at the flow "tee". Pump/squeeze 18 bbls additional acid (50 bbls acid total) followed by 50 bbls FIW to overdisplace the acid into the perforations (by 18+ bbls). Do not exceed 3500 psi surface pressure on the coiled tubing x production tubing annulus. Coordinate with Production Operator to monitor tbg x csg annulus during squeeze operations. NOTE: Pump acid at the maximum rate possible without exceeding the pressure constraints. If the production tubing is in communication with the tbg x csg annulus, hold positive "backpressure" on the annulus to prevent acid from entering the annulus. 16. POOH. RD CTU. 17. Backsurge approximately 50 bbls to surge tank. Let well stand static overnight to let backsurge solids drop to bottom. 18. Return well to injection. A3314AT. PRG Page 4 N1A¥ 1 7 1994 g~s~ u~ & Gas Cons. Commission Anchorage NTDDLE GROUND SHOAL No. A33. i¢ COTLED TUBING CLEAN OUT & XYLENE/ACID ,REATMENT ATTACHNENT NO. 2 CTU SURFACE HANDLING EQUIPHENT FOR RETURN FLUTD TREATHENT OR DISPOSAL 1. RU 250 bbl surge tank for containment of contaminated fluid returns. 2. RU return line choke manifold to take returns from the flow "tee" to either the 250 bbl surge tank or the group production separator. RU a sampling valve at the choke manifold to monitor pH and H2S of the return fluids. All uncontaminated fluids can go directly to the group production separator. Divert all contaminated fluid to the surge tank for processing. 3. RU to transfer contaminated fluid from the surge tank to the A41-11 disposal well at an expected injection rate of 5 BPM @ 1500 psi. (Manifold pump intake with FIW access, in addition to the surge tank access, to overdisplace all contaminated fluid with a minimum of 215 bbls FIW flush. This flush volume will overflush the wellbore capacity by a minimum of 100 bbls.) NOTE: Pump Operator must keep a detailed record of date, time, shut-in pressure before injection, injection rate, fluid type, beginning & ending injection pressure, Instantaneous Shut-In Pressure (ISIP), final shut-in pressure after injection, and volume each time fluid is pumped into C44-14RD. Refer to Attachment No. 3 for Disposal Guidelines and record disposal operations data on the attached form. 4. RU H2S monitoring/detection equipment at the circulating choke and surge tank. Coordinate with SWEPI Production Operator to sample and monitor fluid returns and treat if necessary. 5. Install emergency overflow lines for the surge tank. One to divert fluids to the day tank and one to relieve gas to the flare. Install a flame arrester in the gas flare line. NOTE: Refer to Attachment No. 4 and follow the "Guidelines for Handling Backflowed and Circulated Fluids For Discharge" for all returns not disposed of in A41-11. The Onshore Operator should be notified and prepared to divert any transferred contaminated fluid to the holding tanks. This will allow further dilution and processing of any contaminated fluid prior to processing through the plant for discharge. A3314AT.PRG Page 5 RECEIVED MAY 1 7 1994 Alaska Oil & Gas Cons. Commission Anchorage MTDDLE GROUND SHOAL No. A33-14 CO]LED TUBING CLEAN OUT & XYLENE/ACTD TREATMENT ATTACHMENT NO. 3 A44-1! DTSPOSAL PROCEDURE GUZDEL'I'NES 1. Pump Operator must keep a detailed record of date, time, fluid description, shut-in pressure before injection, injection rate, beginning & ending injection pressure, Instantaneous Shut-In Pressure (ISIP), final shut-in pressure after injection, and volume each time fluid is pumped into A44-11. Complete the Disposal Record Form to document all disposal activity. 2. Establish Filtered Inlet Water (FIW) injection into A44-11 at a minimum injection rate of 4 BPM. Maximum injection pressure is 3500 psi without consulting Engineering or Manager Alaska Operations. 3. If injectivity is acceptable, close FIW access and open pump intake to disposal fluids. Pump disposal fluids into A44-11 at a minimum injection rate of 4 BPM. Maximum injection pressure is 3500 psi unless injectivity drops below 3 BPM. If injectivity drops below 3 BPM at 3500 psi, increase pressure up to 4500 psi maximum injection pressure. Shut down pumps immediately if pressure exceeds 4500 psi or "screen-out" conditions are apparent! 4. Close disposal fluid access and open pump intake to FIW to flush disposal fluid with a minimum of 215 bbls FIW (over-flush wellbore capacity by a minimum of 100 bbls). 5. Shut down disposal operations, record ISIP, and monitor A44-11 fall-off pressure for 30 minutes. Record all data on attached A44-11 Disposal Record Form. 6. Send a copy of the completed form to Production Engineering in Anchorage. Retain a copy of the form for the Platform files. A44-11 DISPOSAL RECORD FORM Send a copy of the completed form to Production Engineering in Anchorage and Chris Willoughby in Kenai. Retain a copy of the form for the Platform files. DATE 30 MIN PRIOR BEGIN END AFTER FLUID SI INa. INa. INa. INa. SI TIME DESCRIPTION PRESS RATE PRESS VOLUME PRESS ISIP PRESS (psi) (BPM)(psi)(bbls) (psi) (psi)(psi) A3314AT. PRG Page 6 RECEIVED MAY 1 7 1994 ~ta~ka u, & Gas Cons. Commission Anchorage ?i~DDLE GROUND SHOAL No. A33-14 COILED TUBING CLEAN OUT & XYLENE/ACID TREATMENT ATTACHMENT No. 4 PROCEDURES FOR HANDLING BACKFLONED AND CIRCULATED FLU]DS FOR DISCHARGE All backflowed and circulated fluids, and not disposed of via A41-11, must be routed through the group separator prior to being sent to the Onshore Facility for discharge. Emulsion breaker should be added as required. Bottle testing is recommended to determine the concentration of breaker. Monitor fluids for H2S and add appropriate scavenging chemicals as required. Note: Ensure any acid treatment fluids that are circulated or backflowed are neutralized prior to sending to the production separator. To satisfy EPA requirements, if the amount of fluid exceeds 250 bbls at one time, the Onshore Operator must take samples of all completion and/or well treatment fluids at the onshore discharge line. Samples must be sent to C&G labs in Anchorage for oil/grease and pH analysis. The Onshore Operator should label samples with description of fluid and date, such as: "Fluid returns from A33-14 acid treatment - xx/xx/94". Notify Onshore Operator when the fluid is being sent. NOTE: If operations result in a significant quantity of contaminated return fluids, the Onshore Operator should be notified and prepared to divert the transferred fluid to the holding tanks. This will allow further dilution and processing of any contaminated fluid prior to processing through the plant for discharge. A3314AT. PRG Page 7 RECEIVED ~A¥ ] 7 1994 Alaska Oil & Gas Cons. Commission Anchorage April 22, 1994 Shell Western E&P In=~ 601 West Fifth Avenue · State 800 Anchorage, Alaska 99501 Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT. SUBMITTAL OF REPORT OF SUNDRY WELL OPERATIONS (FORM 10-404) for MIDDLE GROUND SHOAL A33-14 REFERENCE: SUNDRY APPROVAL NUMBER 94-068 Enclosed are duplicate copies of the Report of Sundry Well Operations (Form 10-404) for Middle Ground Shoal A33-14. Operations were attempted 3/31/94 and 4/01/94 to perforate additional pay in the "G" Pool but were unsuccessful due to obstructions in the wellbore. If you have any questions or wish to discuss, please call Paul Huckabee at (907) 263-9646. Sincerely, Paul Huckabee Staff Production Engineer RECEIVED APR 28 1994 0ii & Gas Cons. Commission Anchorage STATE OF ALASKA AL~~ A OIL AND GAS CONSERVATION COMMI~*" N REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown __ Stimulate Plugging__ Perforate __ Pull tubing__ Alter casing__ Repair well __ Other X W ± r e '1 -in e 5. l-ype of Well: 6. Datum elevation (DF or KB) 2. Name of Operator Shell Western E&P Inc. Development 116' KB feet 3. Address 601 W. 5th Avenue, Suite 920 Exploratory__ 7. Unit or Property name Anchorage, AK 99501 Strat~graphic Middle Ground Shoal Service X 8. Well Number 4. Location of well at surface Platform "A", Leg 4, Conductor 30 @ 1561'N & 385'W from A33-14 SE corner of Section 11, T8N, R13W, S.M. 9. Permit numb~v~al number At top of productive interval 9061' @ 3008'S & 1417'W from NE corner of Section 14, i/' 67'68~/~4- T8N, R13W, S.M. 10. APl numb At effective depth 50-733-20057-00 10555' @ 3527'S & 1934'W from NE corner of Section 14, 11. Field/Pool At total depth T8N, R13W, S.M. MGS "G" Pool 12. Present well condition summary Total depth: measured 10555 feet Plugs (measured) true vertical 8816 feet Effective depth: measured 10432 feet Junk (measured) true vertical 8705 feet Casing Length Size Cemented Measured depth True vertical depth Structural Conductor Sudace 1871 10-3/4", 40.5#, J-55, BTC 1500 sx 0 - 1871' 0 - 1739' Intermediate Production 10531' 7", 23-29# N-80 Buttress 1100 sx 0' - 10531' 0' - 8795' L~ner 1476' 5", 18~, N-80 Buttress 150 sx 8956' - 10432' 7438' - 8705' Perforation depth: measured 9715'- 10419' (5 intervals) true vertical 8073' - 8693' Tubing (size, grade, and measured depth) 3-1/2", 9.2#, N-80 Buttress @ 8949' Packers and SSSV (type and measured depth) TIW PBR set @ 8970' R E C E [ V E D 13. Stimulation or cement squeeze summary APR 28 1994 Intervals treated (measured) N/A Aiaska 0ii & Gas Cons. Commission Treatment description including volumes used and final pressure Anchorage 14. Re0resentative Daily Average Production or Iniection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation N/A N/A 1537 .'" 20 3700 Subsequent to operation N/A N/A 105 400 3750 15. Attachments: ! 16. Status of well classification as: Copies of Logs and Surveys run Daily Report of Well Operations -~- Oil__ Gas__ Suspended__ Service Injector 17. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed~--~-..~dr~ Title Staff Production Engineer Date Form 10-404 Rev 06,15/88 SUBMIT IN DUPLICATE *' DALLY REPORT *' *' PLATFORM: A WELL: A33-14 01-Apr-94 FOREMAN' R.H. SELTZ *' AFE: 263697 ENGINEER: P T HUCKABEE *' AUTH: $ DALLY: $~1;)°'''' CUMULATIVE: $ "7 E'o *' DAI YTD: .... 0 TRI Y'rD: .... 1 DAYS & DAYS ESTIMATED: OF *' COMMENTS: NO ACCIDENTS REPORTED FLUID TYPE: INJECTION WATER WEIGHT: *, *' SPILLS: NO SPILLS REPORTED RT TO TBG HANGER: TOF: *, SUMMARY OF OPERATIONS: *' TIME AND *, ""12.00 HRS - fl/U SCHLUMBERGER TO PERFORATE - TEST LUBRICATOR TO 3000 PSI *' M/U GUNS & RIN TO PERFORATE 26' SECTION - 10,029' - 10,005' *, *' NOTE; GUNS SET DOWN @ 9960' - P/U AND WORK, COULD NOT GET PAST 9960' *, *' PULL GUNS BACK INTO TBG TAIL TO MAKE SURE NO PROBLEMS WITH GUNS *, *' DECISION WAS MADE TO PERFORATE TOP PERFS ~ 9855' - WHEN OPERATOR *' *' STARTED DOWN, NOTICED BAD SPOT IN CABLE (WIRE OPENING UP) WORKED *' LINE IN AN ATTEMPT TO CORRECT PROBLEM - NO LUCK - POOH & L/D GUNS - *' *' PULL CABLE DRUM OUT OF UNIT - WAITING ON NEW CABLE *' DALLY REPORT *' *' PLATFORM: A WELL: A33-14 02-Apr-94 FOREMAN: R.H. SELTZ *' *' AFE: 263697 ENGINEER: P T. HUCKABEE *' *' AUTH: $ DALLY: $750.00 CUMULATIVE: $1500 *' *' DAI YTD: .... 0 TRI YTD: .... 1 DAYS & DAYS ESTIMATED: OF *' *' COMMENTS: NO ACCIDENTS REPORTED FLUID TYPE INJECTION WATER WEIGHT: *' *' SPILLS: NO SPILLS REPORTED RT TO TBG HANGER TOF *' *'24.00 HRS - WAITE ON BOAT TO BRING NEW ELECTRIC LINE - LOADOUT SCHEDULED FOR 1700 HRS *' 4-1-94. - R/U NEW WlRELINE - M/U GUNS - TIH - TAG OBSTRUCTION *' IN TBG AT APROX. 4570' - POOH - R/D GUNS & LUBRICATOR - MOVE TO A33-11LS *' TO RUN PRODUCTION LOG *' NOTE; WHEN BACK FLOWING WELL NOTICED FLUID WAS VERY BLACK - WELL WAS SHUT IN ON 3-29-94 *' *' POSSIBLY THERE IS A PROBLEM WITH BACTERIA GROWING IN CASING & TBG? dr' :: RECEIVED :: *' APR 28 1994 *' *' Ataska 0il & Gas Cons. Commission *' *' Anchorage *' *~********************************************~~**************************************************************************~ *' ADDITIONAL COMMENTS' DRILLS, VISITORS, INSPECTORS ETC. dr' *~****************************************************************************************************** "SUMMARY OF DAILY COST" March 1 O, 1994 Shell Western E&P Inc. O 601 West Fifth Avenue · State 800 Anchorage, Alaska 99501 Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT' SUBMITTAL OF APPLICATION FOR SUNDRY APPROVALS (FORM 10-403) for MIDDLE GROUND SHOAL A33-14 Enclosed in triplicate is the Application for Sundry Approval to perforate additional intervals in the "G" pool in the MGS A33-14. The work is planned to begin around March 19, 1994. If you have any questions or wish to discuss, please call Paul Huckabee at (907) 263-9646. Sincerely, Paul Huckabee Staff Production Engineer RECEIVED MAR I I 1994 A~aska Oil & Gas Cons. Commission Anchorage AKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon __ Suspend__ Operation shutdown __ Re-enter suspended well Alter casing __ Repair Well m Plugging m Time extension Stimulate Change approved program __ Pull tubing ~ Variance Perf--'~rate__X Othe'~'-' 5. ~ype ct Well: 6. Datum elevation (DF or KB~ i2. Name of Operator Shell Western E&P Inc. Development 116' KB feet _ ..... 3. Address 601 West 5th Avenue, Suite 920 Exploratory 7. Unit or Property name Anchorage, AK 99501 Strat~graphic Middle Ground Shoal Service X 8. Well number 4. Location of well at Platform "A", Leg 4, Conductor 30 @ 1561'N & 385'W fr°m SE A33-14 sudace comer of Section 11, TSN, R13W, S.M. 9. Permit number At top of productive 9061' @ 3008'S & 1417'W from N.E. comer of Section 14, T8N, 67-68 interval R13W, S.M. 10. APl number At effective depth 50-733-20057-00 10555' @ 3527'S & 1934'W from N.E. comer of Section 14, T8N, 11. Reid/Pool At total depth R13W, S.M. MGS "G" Pool 12. Present well condition summary Total depth: measured 10555 feet Plugs (measured) true vertical 8816 feet Effective depth: measured 10432 feet Junk (measured) true vertical 8705 feet Casing Length Size Cemented Measured depth True vertical depth Structural Conductor Surface 1871' 10-3/4" 40.5#, J-55, BTC 1500 sx 0 - 1871' Intermediate Production 10531' 7" 23-29# N-80 Buttress 1100 sx 0 - 10531' 0 - 8795' Liner 1476' 5" 18~ N-80 Buttress 150 sx 8956' - 10432' 7438' - 8705' Perforation depth: measured 9715'- 10419' 5 Intervals RECEIVED Tubing (size, grade, and measured depth) 3-1/2", 9.2#, N-80 Buttress @ 8949' MAR 1 1 1994 Packers and SSSV (type and measured depth) TIW PBR set @ 8970' A[A$~3. tJli & Gas Cons. Commission Anchorage 13. Attachments Description summary of proposal ~ Detailed operations program ~ BOP sketch ,,, 15. Status of well classification as: 14. Estimated date for commencing operation /1~,4,,~..~ I~j ~ I'~ ~- ..... Oil Gas Suspended 16. If proposal was verbally approved -- ~ Service Injector Name of approver Date approved 17. I her,~ertify ti' ~going is true and correct to the best of my knowledge Signecl~ -{"--~ ~t'__ Title Staff Production Sngineer Date ~,/IOI~Z FOR COMMISSION USE ONLY .... Conditions of approval: Notify Commission so representative may witness [Approval No,:~ Plug integrity__ BOP Test._ Location clearance__I '~/./Z' Mechanical Integrity Test._ Subsequent form required 10- J.t c~ 4 Approved Copy Original Signed By Returned Approved by order of the Commission David W. Johnston ~ -/9-~,./ Commissioner Date ~///,?/~ ~./.. Form 10-403 Rev 06/15/88 SUBMIT IN TRIPLICATE APPLICATION FOR SUNDRY APPROVAL ATTACHMENT - DESCRIPTION SUMMARY OF PROPOSAL MIDDLE GROUND SHOAL No. A33-14 PERFORATE HE-HF, HI-HK, & HK-HN 1. RU Schlumberger Electric Wireline Unit (EWLU) and perform the following operations to perforate the HE-HF, HI-HK, and HK-HN Pools. a) Test lubricator to 3700 psi +. b) RIH w/ 2-1/8" Retrievable Strip Phased Enerjet guns loaded 6 SPF and correlate to Schlumberger's Gamma Ray/Collar Locator Log dated 5/26/84 (reference Schlumberger Dual Induction - Laterlog, Run #1, dated 11/30/67). Use color coded markers to flag wireline depths as needed to aid depth correlation during subsequent perforating operations. c) Perforate with 2-1/8" Retrievable Strip Phased Enerjet guns loaded 6 SPF at the following depths. SWEPI DRESSER ATLAS DIL INTERVAL ZONE PERFORATION DEPTHS FOOTAGE HE-HF 9860' - 9888' 28' HI-HK 9954' - 9995' 41' HK-HN 10007' - 10060' 53' 122' RD EWLU. Gas Cons. comm'tss'mn Anchorage Shell Western E&P Inc O 601 West F~fth Avenue · Suture 800 Anchorage, Alaska 99501 August 7, 1991 Ms. Joan Miller State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99502 Dear Ms. Miller: SUBJECT: MONTHLY INJECTION REPORT FOR THE MIDDLE GROUND SHOAL FIELD (MGS) FOR THE MONTH OF JULY, 1991 The Monthly Injection Report for the Waterflood project at MGS for July is enclosed in duplicate. If you have any questions regarding this report, please call Ms. Susan Murnan at (907) 263-9614. Very truly yours, W. F. Simpson Manager Regulatory Affairs Alaska Division WFS/slm Enclosures \AOGCC\MTHLYINJ.JULY ( ( Shell Western E&P Inc. O 601 West Fifth Avenue · Suite 800 Anchorage, Alaska 99501 June 11, 1990 Alaska Oil and Gas Conservation Commission ATTN: Elaine Johnson 3001 Porcupine Drive Anchorage, Alaska 99501 SUBJECT: TRANSMITTAL OF REQUESTED INFORMATION REGARDING THE SWEPI OPERATED MIDDLE GROUND SHOAL FIELD Dear Ms. Johnson: In a recent telephone conversation you discussed with Ms. Susan Brown-Maunder information that would be helpful to you if we could provide it. Enclosed, for your convenience and use, are the following: location surveys showing the location of Platform A list of conductor/well locations (in relation to the SE corner of Sec. 11, T8N, R13W) for Platform A wells location survey showing the location of Platform C list of conductor/well locations (in relation to the SE corner of Sec. 23, T8N, R13W) for Platform C wells In addition you requested a revised copy of the Well Completion or Recompletion Report and Log (10-407) for the recently completed well C2]-23. The well location at the top of the producing interval and the well location at total depth as been changed to reflect the actual surveyed location. If you have any further questions regarding these matters, please continue to contact Susan Brown-Maunder at (907) 263-9613. Very Truly/Yours, W. F. Simpson Manager, Regulatory Affairs Alaska Division WFS/SBBM/vj Enclosures cc: Susan Elsenbast-AOGCC \ L ETT ERS \AOGC C \061190. DOC RE '¢EIVED JUN ! ]990 Alaska Oil a gas Cons, Common,il Anchorage ¢ MIDDLE GROUND SHOAL P1 atform "A" WELL/CONDUCTOR LOCATIONS Leg I - Center of Leg i @ 1627'N & 435'W from SE corner of Sec.11, T8N, R13W, S.M. A 12-01 I 1632'N & 437'W from SE corner A 11-01 2 1632'N & 432'W " " " A 43-11 3 1630'N & 430'W " " " A 34-11 4 16 25 ' N & 430 ' W " " " A 34-14 RD 5 1622'N & 433'W " " " A 22-14 6 1622'N & 437'W " " " A 12A-01 7 1625'N & 440'W " " " A 13-01 8 1630'N & 440'W " " " Leg 2 - Center of Leg 2 @ 1681'N & 372'W from SE corner of Sec.11, T8N, R13W, S.M. A 42-11 9 1685'N & 374'W from SE corner A 44-02 10 1685'N & 370'W " " " A 42-14 11 1683'N & 368'W " " " A 41A-11 12 1678'N & 368'W " " " A 11-12 13 1675'N & 371'W " " " A 11-13 RD 14 1675'N & 375'W " " " A 31-14 15 1678'N & 378'W " " " A 44-11 16 1683'N & 378'W " " " Leg 3 - Center of Leg 3 @ 1620'N & 321'W from SE corner of Sec.11, T8N, R13W, S.M. Leg 4 - Center of Leg 4 @ 1566'N & 383'W from SE corner of Sec.11, T8N, R13W, S.M. A 33-11 25 A 14-01 26 A 12-12 27 A 24-01 28 A 13-12 29 A 33-14 30 A 41-11 31 A 23-01 32 1571'N & 385'W from SE corner 1571'N & 381'W " " " 1568'N & 378'W " " " 1564'N & 378'W " " " 1561'N & 381'W " " " 1561'N & 385'W " " " 1569'N & 388'N " " J U t'l 1 1990 ~;laska Oil & Gas Corm. Gommission Anchora¢ SBBC/mgs A (: ! T9N S.U. I [ - I · ___ __, ' ~ , ~ .~'~Ti~..~:~i'~i~ .....--~.. .....--~-~...~.i~-,; ........... ~: : .: ADL IBT54 .: ~ lO ~ It 12 T ZONE 4 , . , ..... , ....... . I I o I I t S s I i - ~ ) t t s I.I I e I I ! I I t mi 16 15 14 l] Il , . ,, , J .... ., ~ , ,,, .~ .... .,, , . ,, , ~~ r "~" ~s~ ' 2g 2T ~ 26 25 .30 .. , ! .... , ,, , .... REEEIVl D , : ' LOCATION OF ' -'JU~J~ ~ 19[~i) SELF CONTAINEO DRILLINO ~,1~o ~ii & Gas Cons. ( remission PRODUCINO PL.',T FORM TgN S.M. , gilchora~' SHELL MIDDLE GROUND S}IOAL .... " - ' - PLATEO~M "~" ,I~ TTN S.M., t ,' : COOK INLET, ALA o 4003 eooo t2ooo APPLICATION BY SH}':.LL OIL CO. _____['.~'~'~"z~'~- -' :_--.---::-- ~ ........ ~::---:'-? '-' LOS ANGELES, CALIFORNIA ~i T. 8N. R 13W. S M 3 2 ~ ' ' ' ' I0 ADL 14 I0 15 LEG NO. 1,,~'~3" 14 2 II LEG NO. I LEG NO. PLANE X = 2;52,785 X= 232,846 Y = 2,485,845 Y =2,485,897 1627' N B~ 435'W FROM THE SE COR. OF SEC. II,TSN, RISW, SM. LE 6 NO. COORDINA TE.$ X= 232,896 Y = 2,485,835 PUBLIC LAND 1681' N 6 372' W FROM THE SE COR. OF SEC. II, T8N, RISW, SM. DE.S CR'I P T/ON 1620'N 8~ 321' W FROM THE SE COR. OF SEC. II, T8N, RISW, SM. LEG NO. 4 X= 232,833 Y =2,4'85,78;5 1566'N I~ 383'W FROM THE SE COR. OF SEC. II, T8N,RI3W, S.M. LAT. - 60°47'44839" LONG.' 151° 29'45 112"' GEODE'TIC COORDINA TE'S LAT. - 60°47'45 $68" LAT. - 60°47'44.7G8'' LONG.-151°29' 45.942" LONG.-151°29' 42/899" LAT.- 60°47'44.244'' LONG.- 151° 29' 44.154" .,.-,, ~ i'l-~l~Y Z- 41 0 - 2 ~ ~,,~.~"~" ~ ~." '~ SHELL OIL CON"" ~' I)ATE MAY 12, 1965 . ~ LOCATe.0'~_ 0~_ ..... ,, .. ........ Shell Western E&P Inc. 601 West F~fth Avenue · Suite 810 Anchorage, Alaska 99501 January 17, 1990 Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Gentlemen: SUBJECT: CANCELLATION OF OUTSTANDING REPORT OF SUNDRY WELL OPERATIONS FOR MGS WELL NOS. A33-14, A12-12, A23-OIRD, A34-11, A34-14RDII, A44-11, A13-12RD AND C31-26 Enclosed are two copies of the Report of Sundry Well Operations for MGS well nos. A33-14, A12-12, A23-OIRD, A34-11, A34-14RD II, A44-11, A13-12RD and C31-26. These workovers were all cancelled and none of the work was performed. If you have any questions concerning these reports, please contact Susan Brown-Maunder at (907) 263-9613. Very truly yours, W. F. Simpson Manager, Regulatory Affairs Alaska Division WFS/raf Enclosures SBBL/aogcc. 011790 ALS STATE OF ALASKA KA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1 Operations pedormed Operation shutdown __ Sbmulate __ Plugging __ Pull tubing __ Alter casing __ Repair well __ Perforate __ Other L CANCELLED 2. Name of Operator 5 Type of Well Shel '1 Western E&P I nc. Development__ Exploratory m 3 Address 601 West Fifth Avenue, Suite 810 Strat~graph~c Serwce "X- Anchoraoe: AK 99501 4. Locabon of well at surface Platform 'A", Leg 4, Conductor 30 ~ 1561' N & 385' W from SE Corner of Section 11, T8N, R13W, S.M. At top of productwe ~nterval 9061' 3008'S and 1417'W from N.E. Corner of Sec. 14, T8N, R 13W, S.M. 6 Datum elevation (DF or KB) 116' KB 7 Unit or Property name Middle Ground Shoal Well number Permit number/approval number 67-68 / 9-685 At effective depth At total depth 12. Present well condition summary Total depth measured 10,555 ' feet true vertical feet Plugs (measured) 10 APl number 50-- 75~-20057-00 11. Reid/Pool Effective depth measured 10,432 ' feet true vertical feet Junk (measured) Casing Length Structural Conductor Surface Intermediate 10,531 ' Production 1,476 ' Liner Perforabon depth measured 9,715'-10,419' 5 Interva'l s true vertical S~ze Cemented 7" 23-29# N-80 Buttress 5" 18# N-80 Buttress Measured depth 0'-10,531 ' 8,956'-10,432' True vertical depth feet Tub~ng(s~ze, grade, and measured depth) 3-1/2", 9.2#, N-80 Buttress @8,949' Packers and SSSV (type and measured depth) PBR set ~ 8,970' 13 Stimulation or cement squeeze summary Intervals treated (measured) N/A Treatment descnpbon including volumes used and hnal pressure 14. Prior to well operation Subsequent to operation Representative Daily Average Production or Injection Data Od-Bbl Gas-Md Water-Bbl Casing Pressure Tubing Pressure 15, Attachments Cop~es of Logs and Surveys run __ Daily Report of Well Operations __ 16. Status of well classification as. Oil X.~ Gas__ Suspended __ Service 17. I hereby cerbfy tha~t~e foregoing is true and correct to the best of my knowledge. Signed '~.~'X~, J.~~ Title DIVISIONOPERATIONSMGR. Form 10-404 Rev 06/15/88 SBBL/r swo .0115901 Date 01/17/90 SUBMIT IN DUPLICATE Shell Western ~=P Inc. '~ 601 West Fifth Avenue · Suite 810 ~ Anchorage, Alaska 09501 0 R I [; I August 8, 1989 Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 SUBJECT: TRANSMITTAL OF APPLICATIONS FOR SUNDRY' APPROVAL FOR MIDDLE GROUND SHOAL WELLS A12-12, A23-OIRD, A33-14, A34-11, A34-14RDII, AND A44-11. Enclosed, in triplicate, are six Applications for Sundry Approval for Middle Ground Shoal wells. The workovers involve stimulating the wells with 15% HC1. The work is scheduled to begin as soon as approval is received from your office. If you have any questions regarding this matter, please contact Susan Brown-Maunder at (907) 263-9613. Very truly yours, ~g/Io: W. F. Simpson Manager, Regulatory Affairs Alaska Division MLW/SBBM/dl Enclosures RECEIVED AUG 1 "' 1°~'~ Ataska Oil & Gas Cons. Commission Anchorage SBBJ/aogcc. 080889 SBBJ/a sa. 073189c ~.IUIJI¥11 I I1~1 I IllrLIbt~l r STATE OF ALASKA ALASKA OIL AN D GAS CONSERVATION COM MISSION APPLICATION FOR SUNDRY APPROVALS 1 Type of Request Abandon __ Suspend __ Alter casing __ Repair well Change approved program __ Operation shutdown I Re-enter suspended well __ Plugging ~ T~me extension t Stimulate X Pull tubing __ Vanance __ Perforate __ Other 2 Name of Operator Shell Western E&P Inc. 3 Address 601 West Fifth Avenue, Suite 810 Anchorage, AK 99501 5 Type of Well Development __ Exploratory Strabgraph~c Serwce 4 Locabon of well at surface Platform "A", Leg 4, Conductor 30 ~ 1561'N & 385'W from SE corner of Sec 11, T8N, R13W, S.M. At top of producbve ~nterval 9061' 3008'S & 1417'W from N.E. Corner of Sec. 14, T8N, R13W, S.M. At effecbve depth 6. Datum elevation (DF or KB) 116' KB 7. Unit or Property name Middle Ground Shoal 8. Well number A33-14 9. Permit number 67-68 10 APl number 50-- 733-20057-00 At total depth (10,555') 3527'S & 1934'W from N.E. corner Sec. 14, T8N, R13W, S.M. 12 Present well condition summary Total depth measured 10,555' feet Plugs (measured) true verbcal feet 11 Reid/Pool "G" Pool feet Effecbve depth measured 10,432' feet Junk (measured) true verbcal feet Casing Length S~ze Cemented Structural Conductor Sudace Intermediate 10,531 ' 7" 23-29# N-80 Buttress Production 1,476' 5" 18# N-80 Buttress Dner Perforation depth measured 9,715 ' -10,419' 5 intervals true vertical Measured depth True vertical depth 0'-10,531 ' 8,956' -10,432 ' RECEIVED Tubing (s~ze, grade, and measured depth) 3-1/2", 9.2#, N-80 Buttress ~ 8,949' Packers and SSSV (type and measured depth) PBR set ¢ 8,970' 13. Attachments Descnption summary of proposal AUu . Gas Cons C0rnmlssio~ Detaded operabons program ~ BOP sketch __ 14 Estimated date for commencing operation I As soon as approval is received. X 16 If proposal was verbally approved O~1 __ Gas ~ Name of approver Date approved Serwce injector 17. I hereby certify tM the foregoing ~s true and correct to the best of my knowledge FOR COMMISSION USE ONLY 15. Status of well class~flcabon as. Suspended__ Conditions of approval. Nobfy Commission so representabve may witness Plug ~ntegnty __ BOP Test __ Locabon clearance __ Mechanical Integnty Test __ Subsequent form required 10- Approved by order of the Commission Original Signed By David W. Johnston IAppr°val N°'¢ --~? ~.~'-- Approved Copy Returned Commissioner Date 9 ~/0"~ Form 10-403 Rev 06/15/88 SBBJ/asa .073189a SUBMIT IN TRIPLICATE PROGNOSIS MGS A 33-14 OPERATION' Pump acid into water injection well. OBJECTIVE' Increase water injection rate from 1,300 to 1,550 BWPD. COMPLETION EQUIPMENT' See attached completion equipment detail dated March 26, 1987. STATUS' The current water injection rate is about 1,300-1,400 BWPD. On January 1, 1989, water injection rate was about 1,550 BWPD. ACID REQUIREMENTS. 2,000 gallons of 15%HC1 w/Inhibitor. PROCEDURE- 1. Rig up D.S. pumping equipment and test all lines and equipment to 5,000 psi using filtered injection water. Test acid for strength by titration method, to be witnessed by SWEPI representative. 2. Pump 2,000 gallons of 15% HC1 with inhibitor into well followed by filtered injection water. Place well back on injection. Surface pressure on well will be 3,500 psi while on injection. RD D.S. 3. Note any change in injection rate on Morning Report. RECOMMENDED: DATE' APPROVED' DATE' HAVS/072589 · / · May 5, 1989 Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Shell Western E&P Inc. 601 West Fifth Avenue, Suite 810. ?/--~' J.~.~.-_TVI ~-~'~ Ancho,age, Alaska 99501 -- l J T 'r Y CH I'- / Gentlemen: SUBJECT: AREA INJECTION ORDER NO. 9 (CENTRAL PORTION MIDDLE GROUND SH(1AL FIELD), RULE 6 As part of the requirements of Area Injection Order (AID) No. 9, Rule 6, a schedule for performing radioactive tracer surveys (RTS) must be submitted to and approved by the commission. During conversations with members of your staff it was indicated that the Commission may accept recent RTS's even though the commission representatives did not have the opportunity to witness the surveys. By way of this letter, SWEPI is submitting our schedule for performing RTS's on in,iection wells and request that you accept the recent surveys as satisfying the requirements of Rule 6 based on the enclosed RTS logs. {See Attachment l for list of enclosed logs.) Attachment 2 is a table showing the mechanical integrity history for the MGS injection wells. Also shown is the proposed testing schedule noting those wells for which we are asking )/our acceptance of the previously run surveys. Your early review of this proposal would be greatly appreciated. If we can be of further assistance, please do not hesitate to call Ms. Susan Brown-Maunder at (907) 263-9613. Very truly yours, I,'/o'. W. F. Simpson Manager Regulatory Affairs SBBM/hr Enclosures GTK1/050489 LIST OF ENCLosED LOGs ' U17/'86 NTt .. 3/4/88 NFL. 3/5/88 ~AFiT' 6./,1_7/~7 ~N ' ?.~_/~ "" ,vz6/88 NFL .. i/~/87 NFL .. 2/1~/87 NFL .. 1/37/87 NFL .. 2/10/87 NFL .. 2-/12./87 NFL .. 101'24/87 RECEIVED MAY - 5 1989 Alaska Oil & Gas Cons. Commission Anchorage 6TK1/050489 Shell Western E&P Inc. 601 West F~fth Avenue · Suite 810 Anchorage, Alaska 99501 July 11, 1988 Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Gentlemen- SUBJECT' REPORT OF SUNDRY WELL OPERATION FOR MIDDLE GROUND SHOAL WELL A33-14 STIMULATION Enclosed, in duplicate, is the Report of Sundry Well Operation for Middle Ground Shoal well A33-14. The stimulation of this well occurred on June 29, 1988. The job was performed as prognosed. If you have any questions, please call Ms. Susan Brown at (907)263-9613. Sincerely, W. F. Simpson Manager Regulatory Affairs Alaska Division WFS/SBB/1 jm Enclosures RECEIVED .IIJL 1 1 ]988 Alaska Oil & Gas Cons. Commission Anchorage SBBH/ros .071188 ~'~ STATE OF ALASKA I~ ALAS OIL AND GAS CONSERVATION COM .oSlON REPORT OF SUNDRY WELL OPERATIONS 10perahons performed: Operahon shutdown [] Stimulate [] Plugging [] Perforate [] Pull tubing [] Alter Casing [] Other [] 2 Name of Operator 5 Datum elevation (DF or KB) Shell Western E&P Inc. 116' KB Feet 3. Address 6. Unit or Property name 601 West Fifth Ave., Suite 810, Anchorage, AK 99501 Middle Ground Shoal 4. Location of well at surface Platform "A", Leg 4, Conductor 30 ~ 1561'N & 385'W from SE corner of Sec 11, T8N, R13W, S.M. At top of productive ~nterval 9061 ' 3008'S & 1417'W from N.E. Corner Sec. 14, TSN, R13W, S.M. At effective depth At total depth (10,555') 3527'S & 1934'W from N.E. corner Sec. 14, T8N, R13W, S.M. 7 Well number A33-14 8 Approval number 8-512 9 APl number 50-- 733-20057-00 10. Pool "G" Pool 11 Present well condlhon summary Total depth: measured true verbcal 10,555 ' feet feet Plugs (measured) Effective depth, measured 10,432 ' true vertical feet feet Junk (measured) Casing Length Size Structural Conductor Surface I ntermed late 10,531 ' 7" Production 1,476' 5" Liner Perforation depth, measured 9,715'-10,419' Cemented 23-29 18# true vertical 5 intervals Tubing (size, grade and measured depth) 3-1/2", 9.2#, N-80 Buttress ~ 8,949' Packers and SSSV (type and measured depth) PBR set (~ 8970' Measured depth N-80 Buttress N-80 Buttress True Verbcal depth 0 ' -10,531 ' 8,956 ' -10,432 ' RECEIVED JIlL 11 1988 Alaska Oil & Gas Cons. Commission Anchorage 12. Stimulation or cement squeeze summary Acidized lower Hemlock perforations with 1,000 gallons of 10% HCl Intervals treated (measured) and 1,000 gallons 12%/3% mud. Treatment description including volumes used and final pressure 13 Prior to well operation Subsequent to operation Representative Daily Average Producbon or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 1,381 0 psi 3,500 psi 1,158 0 psi 3,500 psi 14. Attachments Daily Report of Well Operabons [] Cop~es of Logs and Surveys Run [] 15 I hereby cerhfy that the foregoing ~s true and correct to the best of my knowledge /~-~'. ~:-,- '~L"~'-~ Signed ~--~' f/4~ Title Division Operations Manager Date July 11, 19, Form 10-404 Rev. 12-1-85 Submit in Duplicate 0730 to 1630 1700 to 1845 1900 to 2130 2145 to 2245 2300 to 0015 0040 to 0150 0200 to 0215 0215 to 0315 0300 to 0430 0530 to 0700 DAILY REPORT OF OPERATIONS A33-14 06/29/88 Rigging up, mixing inhibitor, and pressure testing. Run in hole. Not circulating. Washing fill, tagged at 10,125, washed to 10,299. Spotted and soaked 500 gallon of 10% HC1 acid at 10,299. Circulated down to 10,325, again hit hard fill. Spotted another 500 gal of 10% HC1 acid and soaked. Could not wash any farther than 10,325. Pumped remaining 1,000 gallon 12%/3% HC1/HF away with well on injection. Pull out of hole while injecting. Rigging down and cleaning up. RECEIVED Alaska Oil & Gas Cons. Commfssion Anchorage SBBH/ros .070888 Shell Westem E&P Inc. Q 601 West F~fth Avenue * Suite 810 Anchorage, Alaska 99501 June 29, 1988 Alaska Oil and Gas Conservation 3001 Porcupine Drive Anchorage, A1 aska 99501 Commission Gentlemen- SUBJECT' APPLICATION FOR SUNDRY APPROVAL FOR STIMULATION OF MIDDLE GROUND SHOAL WELL A33-14 Enclosed, in triplicate, is an Application for Sundry Approval for Stimulation of MGS well A33-14. The stimulation is scheduled to begin June 29, 1988. Verbal approval has been given by Blair Wondzell. If you have any questions, please call Ms. Susan Brown at (907)263-9613. Sincerely, ~. L. ~oodson Division Operations Manager Alaska Division MLW/SBB/ljm Enclosures SBBG/asa.062988 RECEIVED Al~sk~ O~t & Gas Cons. Commission A STATE Of ALASKA Al S ,~ OIL AND GAS CONSERVATION COM ,,SSION APPLICATION FOR SUNDRY APPROVALS I Type of Request' Abandon [] Suspend [] Operahon Shutdown [] Re-enter suspended well [] Alter camng [] T~me extension [] Change approved program [] Plugging [] Shmulate ~ Pull tubing [] Amend order [] Perforate [] Other 2. Name of Operator 5 Datum elevation (DF or KB) Shell Western E&P Inc. 116' KB feet 3. Address 6 Unit or Property name 601 West Fifth Ave., Suite 810, Anchorage, AK 99501 Middle Ground Shoal 4. Locahon of well at surface Platform "A", Leg 4, Conductor 30 @ 1561'N & 385'W from SE corner of Sec 11, T8N, R13W, S.M. At top of produchve ~nterval 9061' 3008'S & 1417'W from N.E. Corner Sec. 14, T8N, R13W, S.M. At effective depth At total depth (10,555') 3527'S & 1934'W from N.E. corner Sec. 14, T8N, R13W: S.M. 11 Present well cond~hon summary Total depth measured 10,555 ' feet Plugs (measured) true vertical feet 7. Well number A33-14 8. Permit number 7-144 9. APl number 50-- 733-20057-00 10 Pool "R" Pno! Effective depth measured 10,432 ' feet Junk (measured) true vertical feet Casing Length Size Cemented Structural Conductor Surface Intermediate 10,531' 7" 23-29# 1,476' 5" 18# Production L~ner Perforation depth' measured 9,715 '-10,419' true vertical Measured depth N-80 Buttress N-80 Buttress True Verhcal depth 0'-10,531' 8,956'-10,432' RECEIVED Tubing (size, grade and measured depth) 5 intervals 3-1/2" 9 2# N-80 Buttress @ 8 94~askaOd & Gas Cons. Commis. ' ' ' ' Arlcho~',~O Packers and SSSV (type and measured depth) PBR set @ 8,970' 12 Attachments Description summary of proposal [] Detailed operations program ,[~ BOP sketch [] Prognosis and Completion Equipmc_nt ilPtail .~h~Pt 13. Estimated date for commencing operation June 29, 1988 ~..~. ...... ~_,_,, ....... , 14. If proposal was verbally approved ~~3 No~ _.~~Da~ed..~//_~~__ Name of appr~v~_r Blair Wondzell Date approved June 29 ~1988/8'30, 151 hereb¥,,certify/that,,t,~e foreg~,~g is true and correct to the best of my knowledge Signed//MAx//~/~/.,~__.,i_Jy~_/l'''~Ik~l/ ~f~t.x~,~,* Title Division Operations Manager DateJune 29, 1981 Commission Use Only Conditions of approval Notify commission so representative may witness. _ l. Approval No. [] Plug integrity [] BOP Test [] Loca~l~_~ce~_a~_,~ ~:::~'" ~ / ~ / Heturnea Approved by SIGNED LONNIE C. SMrI'H Commissioner by order of ~-- ~A~ the commission Date Form 10-403 Rev 12-1-85 SBBG/asa.050388 Submit in tripl~cate¢ P ROGNOS I S A33-14 OPERATION: Clean out Fe304 Scale covering the HR-HZ perforation. Acidize all injection intervals. TUBING: See attached Completion Equipment Detail Sheet PERFORATIONS: See attached Completion Equipment Detail Sheet STATUS: Injecting 1702 BWPD @ 3500 psi 5/01/88 NOTE: Fill was encountered with electric line at 10165' on 3/3/88 and is composed of iron oxide. EQUIPMENT NEEDED: ACID REQUIREMENTS: CHEMICAL NEEDED: NOTE: 250 bbl mixing tank 50 bbl neutralizing tank 1 pump unit I jet mixer 1000 gallons 10% HC1 w/inhibitor 1000 gallons 12% HC1/3% HF w/inhibitor 2000# MI SS-II H2S Scavenging Chemical 42 gallons HOWCO FR26L 600# Soda Ash RECEIVED JUN 2 9 :t9,88 Alaska Oil & Gas Con~. Commission 'Anchorage Triple rinse with fresh water plastic liners of SS-II sacks and FR26L container before disposal. PROCEDURE: · RU coiled tubing unit and pumping equipment. RU to take returns through choke to test separator. Bullet nose wash nozzle is to be secured to 1-1/4" coiled tubing with swedge lock or allen screw connector. Wash nozzle is not to be threaded on directly to coiled tubing. Test Acid for strength by Titration method. Pressure test all surface equipment from the pump discharge to the wellhead to 5000 psi. e If coiled tubing contains diesel, flush out to production header. Maintain injection pressure on coiled tubing by continuing to inject while RIH. SEA NOTE: No fluid should be discharged directly overboard without prior approval of SEA representative. All fluid should be sent to Onshore facility. Notify Onshore operator when the fluid is shipped and use the following calculation to determine when samples need to be caught. Samples need to be sent to Chem Lab in Anchorage for oil/grease and pH analysis. Have Onshore Operator label sample (i.e., "frac fluid [date] from completion of A33-14"). JHF4/O50388a ReV BY:Xerox Telecopier ?020 ~ O-2Q-O0 ~10:33A)4 : · 0422?'* 9072790211;~ 1 Page Pipe!ine - ~ BBL ~4 h~s - hfs De]ay - Gross Pt, odu"c-~i'~n jI~(BBL/Da,Y} x + Wo~,kover' Slug {B~L/Day) + Onshore Fact li~y · 1000 BBL 24 hfs · h.s oe~a~ Gross P~o~uc~1~ A.--G: ~ek-ir- x (B6L/Day) Total time between slug shtpment and sample . CLEAN OUT Premtx the circulation ~lutd p~to~ to taggtng fil~i Fluld to be mlxed using a ~let mlxer and stored in a 200 bbl tank. rat mix 10~/bb~ ~% SS-]~ H S scavenging chemtca~ tn 200 bb~ o+ +~ltmr,d tn~ectlon w~tee. Nhen al~ of the SS-II ~s tn soqutton, tdd 0.5~ HONCO FR-26L fr~ct~on ~educe~ to ~e solution. Continua to c~rculmtm until whole tank ts c~plately mixed. Lightly tag fill at 1016B'. Begin taking returns to p.~oductton. Clean out to PBTD at 10432' by circulating with p~emixed fluid, If unable to circulate out debris, spot 500 gal of ~0% HCl and allow to soak on top of debris for 1 hour. Catch any circulated out acid in surface tank and neutrali=e with soda ash 600, soda ash will neut~alt=e SO0 gallons of ~0%HCl' U~e jet mix to ~tx end circulate soda a~h ~o~ nmuteal(=atlon. Allow well to bmckflow to aid tn removal of debris Keep ~ctprocatlng coiled tubing. Do not allow coiled :ubtng to remain ~tmttonary. At PBTO~ circulate all r~alning premixed fluid. Ac,~o oom RECE /EE) '~i~APPROVED: DATE dHF4/OSO388a COMPLETION EQUIPI~ENT DETAIL SHEET IqGS A33-14 3/26/87 NO. ITEM APPROXIMATE TVD. MD. 1. OTIS "X" NIPPLE 2. OTIS "X" NIPPLE 3. TIW LOCATOR 4. TIW TIE-BACK SLEEVE 5. TIW TYPE S PACKER 6. TIW 20' PBR w/SEALS 321 321 7434 8949 7437 8952 7440 8956 7444 8961 7451 8970 CASING 7" 23#, N-BO BUTTRESS @ 0 - 6500' 26#, @ 6500 - 9900' 29#, @ 9900 - 10531' lB#, N-BO BUTTRESS (LINER) @ 8956 - 10432' PBTD = 10,432' TO = 10,555' TUBING 3 1/2', 9.3#, N-80 BUTTRESS @ 8949' PERFORATED ZONE HC-HD HK-HN HN-HR HN-HR HR-HZ GROSS INTERVAL 9715-9804 ' 10060-10162' 10162-10239' I0~760-10302' 10328-I0419' RECEIVED Anchorage PAGE 68 Shell Western E&P Inc. O 601 West F~fth Avenue · Suite 810 Anchorage, Alaska 99501 June 2, 1988 Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Gentlemen- SUBJECT: REPORT OF SUNDRY WELL OPERATION FOR MIDDLE GROUND SHOAL WELL A33-14 STIMULATION Enclosed, in duplicate, is the Report of Sundry Well Operation for Middle Ground Shoal well A33-14. The stimulation of this well occurred on May 13, 1988. The job was performed as prognosed. If you have any questions, please call Ms. Susan Brown at (907)263-9613. Sincerely, W. F. Simpson Manager Regulatory Affairs Alaska Division WFS/SBB/kt Enclosures SBBG/ros.053188 , STATE OF ALASKA r~ ALAS . OIL AND GAS CONSERVATION COM ..~SION REPORT OF SUNDRY WELL OPERATIONS I Operations performed: Operahon shutdown [] Stimulate ~Plugging [] Perforate [] Pull tubing [] Alter Camng [] Other [] 2 Name of Operator 5 Datum elevation (DF or KB) Shell Western E&P Inc. 116' KB Feet 3 Address 6. Unit or Property name 601 West Fifth Ave., Suite 810, Anchorage, AK 99501 Middle Ground Shoal 4. Locahon of well at surface Platform "A", Leg 4, Conductor 30 @ 1561'N & 385'W from SE corner of Sec 11, T8N, R13W, S.M. At top of productive interval 9061' 3008'S & 1417'W from N.E. Corner Sec. 14, T8N, R13W, S.M. At effective depth At total depth (10,555') 3527'S & 1934'W from N.E. corner Sec. 14, T8N, R13W, S.M. 7. Well number A33-14 8. Approval number 8-413 9 APl number 50-- 733-20057-00 10 Pool "G" Pool 11 Present well cond)tlon summary Total depth measured true vertical 10,555' feet feet Plugs (measured) Effective depth' measured 10,432' true vertical feet feet Junk (measured) Casing Length S~ze Structural Conductor Surface I ntermed iate 10,531 ' 7" 1,476' 5" Production L~ner Perforation depth, measured 9,715'-10,419' Cemented 23 -29 18# true vertical 5 intervals Measured depth N-80 Buttress N-80 Buttress True Vertical depth 0"10,531 ' 8,956'-10,432' RECEIVED 3-1/2", 9.2#, N-80 Buttress @ 8,949' Tubing (size, grade and measured depth) !988 Packers and SSSV (type and measured depth) PBR set @ 8970' Alaska 0il & Gas Cons. Commission Anchorage 12. Stimulation or cement squeeze summary Acidized lower Hemlock perforations with 1,000 gallons of 10% HCl Intervals treated (measured) and 1,000 gallons 12%/3% mud. Treatment description )ncluding volumes used and hnal pressure 13 Prior to well operation Subsequent to operatmon Representative Daily Average Production or Injechon Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 1,381 0 psi 3,500 psi 1,158 0 psi 3,500 psi 14 Attachments Daily Report of Well Operations ]~ Copies of Logs and Surveys Run [] 15 I hereby certify that the foregoing )s true and correct to the best of my knowledge Signed ~ Form 10-404 Rev 12-1-85 SBBG/ros.053188 Title Pivision Operations Manager Date .Il Submit in DupliCate DAILY REPORT OF OPERATIONS 05/31/88 RU pumping equipment. Tested acid for strength. Pressure tested all surface equipment to 5,000 psi. Maximum allowable pump pressure was 5,000 psi. Pumped 500 gallons of 10% HC1, 1,000 gallons of 12%/3% mud acid, and 500 gallons 10% HC1 at a pump rate of 0.5 BPM. Displaced acid with filtered injection water when acid reached end of tubing. Rinsed tank and injected rinse water. Continued injection. Ri gged down. RECEIVED ~ u N o 6 lg88 Alaska Oil & Gas Cons. Commissio Anchorage SBBG/rcs. 053188 L STATE OF ALASKA i~~ ALAS . OIL AND GAS CONSERVATION COM ~SION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request. Abandon [] Suspend [] Operahon Shutdown [] Re-enter suspended well [] Alter camng [] Time extension r-;, Change approved program [] Pluggmg [] Stmmulate ~ Pull tubing [] Amend order [] Perforate ~ Other [] 2. Name of Operator Shell Western E&P Inc. 630~'~;sts Fifth Ave., Suite 810, Anchorage, Al( 99501 4. Location of well at surface Platform "A", Leg 4, Conductor 30 ~ 1561'N & 385'W from SE corner of Sec 11, T8N, R13W, S.M. At top o( productive interval 9061' 3008'S & 1417'W from N.E. Corner Sec. 14, T8N, R13W, S.M. At effective depth At total depth (10,555') 3527'S & 1934'W from N.E. corner Sec. 14, T8N, R13W, $,M, 11 Present well condition summary Total depth: measured 10,555' feet Plugs (measured) true vertical feet 5. Datum elevabon (DF or KB) 116' KB feet 6. Unit o,r .Prpp,erty.,name , m'~aale urouno Shoal 7. Well number A33-14 8. Permit number 7-144 9. APl number 50- 733-20057-00 10. Pool "G" Pool Effective depth: measured 10,432 ' feet Junk (measured) true vertical feet Casing Structural Conductor Surface Intermediate Production Lmer Perforation depth: measured Length Size Cemented 10,531' 7" 23-29# 1,476' 5" 18# 9,715'-10,419' Measured depth N-80 Buttress N-80 Buttress True Vertical depth 0'-10,531' 8,956'-10,432' true vertical 5 intervals Tubing (s~ze, grade and measured depth) 3-1/2", 9.2#, N-80 Buttress @ 8,949' Packers and SSSV (type and measured depth) PBR set @ 8970' 12.Attachments Description summary of proposal [] Detailed operations program X Completion Equipment Detail Sheet 13. Estimated date for commencing operahon May 13, 1988 ..~,,~.. ........ , ,,~.~ ,~_~.~ ~ 14. If proposal was verbally approved ~ ~ ~ ~ ~.~~ ~~ Name of app~r B]a~ ~ondze]] Date approved 15. I here~ ce~i~'that the f~regoing is true and correct to the best of my knowledge ,,,e Signed BOP sketch [] May 12, 1986) Date May 20, 1986) Commission Use Only Conditions of approval Notify commission so representative may witness I Approval No. [] Plug integrity []BOP Test [] Location clearance Approved Copy ORIGINAL SIGNED BY Returned Approved by Commissioner by order of the commission Date Form 10-403 Rev 12-1-85 SBBG/asa. 050388 Submit ~n tnplmcate PROGNOSIS A33-14 OPERATION: Acidize Lower Hemlock perforations TUBING: See attached Completion Equipment Detail sheet. PERFORATIONS: See attached Completion Equipment Detail sheet. STATUS: Injecting 1544 BWPD @ 3500 psi (5/4/88) ACID REQUIREMENTS: 1,000 gallons 10% HC1 with inhibitor 1,000 gallons 12%/3% ppg mud acid PROCEDURE: NOTE: All fluid to be filtered through two micron filter. · RU pumping equipment. Test acid for strength using Titration method. Pressure test all surface equipment to 5,000 psi. · Maximum allowable pump pressure is 5,000 psi. Pump 500 gallons of 10% HC1, 1,000 gallons of 12%/3% mud acid, and 500 gallons 10% HC1 at 0.5 BPM. Displace with filtered injection water when acid reaches end of tubing. Rinse tank and inject rinse water. Rig down. SBBG/asa.052088 STATE OF ALASKA ALAS OIL AND GAS CONSERVATION COM ,.,SION APPLICATION FOR SUNDRY APPROVALS 1 Type of Request. Abandon [] Suspend [] Operahon Shutdown [] Re-enter suspended well [] Alter casing [] T~me extension [] Change approved program [] Plugging [] Shmulate '~ Pull tubing [] Amend order [] Perforate [] Other [] 2. Name of Operator Shell Western E&P Inc. 30Address 1West Fifth Ave., Suite 810, Anchorage, AK 99501 4 Locahon of well at surface Platform "A", Leg 4, Conductor 30 @ 1561'N & 385'W from SE corner of Sec 11, T8N, R13W, S.M. At top of produchve ~nterval 9061' 3008' S & 1417'W from N.E. Corner Sec. 14, T8N, R13W, S.M. At effective depth At total depth (10,555') 3527'S & 1934'W from N.E. corner Sec. 14, T8N, R13W, S.M, 11 Present well cond~hon summary Total depth, measured 10 ~555 ' feet Plugs (measured) true vertmal feet 5. Datum elevation (DF or KB) 116' KB feet 6. Unit o,r ProDerty..name . middle ~rouna Shoal 7 Well number A33-14 8. Permit number 7-144 9. APl number 50- 733-20057-00 10 Pool "G" Pool Effective depth, measured 10,432 ' feet Junk (measured) true vertical feet Casing Structural Conductor Surface Intermediate Production L~ner Perforation depth Length S~ze Cemented 10,531' 7" 23-29# 1,476' 5" 18# measured 9,715'-10,419' Measured depth N-80 Buttress N-80 Buttress true verhcal 5 intervals Tubing (s~ze, grade and measured depth) 3-1/2", 9.2#, N-80 Buttress @~a~J9' True Verhcal depth 0'-10,531' 8,956'-10,432' Packers and SSSV (type and measured depth) PBR set @ 8970' 12.Attachments Descriphon summary of proposal [] Completion Equipment Detail Sheet 13 Estimated date for commencing operation May 13, 1988 Detailed operations program BOP sketch [] 14. If proposal was verbally approved ~~ ~ ~ Name ~ Blair Wondzell °~:~]~l:a~--"------~~,-,~J~te approved 15 I-"'~ere~)~at t~'JT~r';g~~'e and correct to the best of my knowledge Signed /~~.~,t~-'~~ Title Division Operations Manager May 12, 1988 Commission Use Only Date May 20, 1988 Conditions of approval Notify commission so representative may witness [] Plug integrity [] BOP Test [] Location clearance Approved by I)~t~ ,t~it $1(INIED BY ~IE C. SMITH Approved Copy Returned Commissioner by order of ...- ... the commission Date ~=~ :"~ - Form 10-403 Rev 12-1-85 SBBG/asa.050388 Submit in tripl)cate~/~ PROGNOSIS A33-14 OPERATION: Acidize Lower Hemlock perforations TUBING: See attached Completion Equipment Detail sheet. PERFORATIONS: See attached Completion Equipment Detail sheet. STATUS: Injecting 1544 BWPD @ 3500 psi (5/4/88) ACID REQUIREMENTS: 1,000 gallons 10% HC1 with inhibitor 1,000 gallons 12%/3% ppg mud acid PROCEDURE: NOTE: All fluid to be filtered through two micron filter. · RU pumping equipment. Test acid for strength using Titration method. Pressure test all surface equipment to 5,000 psi. · Maximum allowable pump pressure is 5,000 psi. Pump 500 gallons of 10% HC1, 1,000 gallons of 12%/3% mud acid, and 500 gallons 10% HC1 at 0.5 BPM. Displace with filtered injection water when acid reaches end of tubing. Rinse tank and inject rinse water. Rig down. SBBG/asa.052088 Shell Westem E&P Inc. 601 West Fifth Avenue · Suite 810 Anchorage, Alaska 99501 May 20, 1988 Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Gentlemen: SUBJECT: APPLICATION FOR SUNDRY APPROVAL FOR UPCOMING STIMULATION OF MIDDLE GROUND SHOAL WELL A33-14 Enclosed, in triplicate, is an Application for Sundry Approval for Stimulation of MGS well A33-14. Ms. S. B. Brown of our office received verbal approval from Mr. Blair Wondzell on May 12, 1988, and the stimulation began as scheduled on May 13, 1988. If you have any questions, please call Ms. Susan Brown at (907)263-9613. Sincerely, Division Operations Manager Alaska Division MLW/SBB/kt Enclosures SBBG/asa.052088 July 14, 1987 Shell Western E&P Inc. 601 West Fifth Avenue · Suite 810 Anchorage, Alaska 99501 Alaska Oil & Gas Conservation Comm. 3001 Porcupine Drive Anchorage, Alaska 99502 Gentlemen: SUBJECT: SUBMISSION OF REPORT OF SUNDRY WELL OPERATIONS FOR MIDDLE GROUND SHOAL WELL NO. A33-14 (APPROVAL #7-144) The stimulation and clean out that was approved on March 10, 1987 (Approval #7-144) has been cancelled. Enclosed, in duplicate, is the Report of Sundry Well Operations for Middle Ground Shoal Well no. A33-14. Ve~ruly yours, /x) Manager ~gul atory/Affairs DLY/SBB/bc ~:',-~:_ 1 5 1987 Aiask.~ Oil & Gas Cons. Commission A~chora¢~ 0714c/SBBF STATE OF ALASKA N~ ALA , OIL AND GAS CONSERVATION CO SSION REPORT OF SUNDRY WELL OPERATIONS I Operations performed Operation shutdown [] Stimulate [] Plugging [] Perforate [] Pull tubing [] Alter Casing [] Other [] 2 Name of Operator Shell Western E&P Inc. 3. Address 601 West Fifth Ave., Suite 810, Anchorage, AK 99501 4 Location of well at surfac~latform "A", Leg 4, Conductor 30 @ 1561'N & 385'W from SE corner of Sec 11, T8N, R13W, S.M. At top of produchve interval 9061' 3008'S & 1417'W from N.E. Corner Sec. 14, T8N, R13W, S.M. At effective depth At total depth(10,555,) 3527's & 1934'W from N.E. corner Sec. 14. T8N. R13W. S,M, 11 Present well condition summary Total depth' measured 10,555' feet Plugs (measured) true vertical feet 5. Datum elevation (DF or KB) 116' RKB Feet 6. Unit or Property name Middle Ground Shoal 7. Well number A33-14 8 Approval number 7-144 9. APl number 50-- 733-20057-00 10 Pool "G" Pool Effective depth, measured 10,432 ' feet Junk (measured) true vertical feet Casing Length S~ze Structural Conductor Surface Intermediate 10,531 ' 7" 1,476' 5" Produchon L~ner Perforation depth measured 9,715'-10,419' true vertical Cemented Measured depth True Verhcal depth 23-29# N-80 Buttress 10,531' 18# N-80 Buttress 8,956'-10,432' 5 intervals Tubing (size, grade and measured depth) 3-1/2", 9.2#, N-80 Buttress @ 8,949' JL 1 ~ !957 Packers and SSSV (type and measured depth) PBR set @ 8970' 12. Stimulation or cement squeeze summary Intervals treated (measured) The stimulation and clean out that was approved on 3/10/87 has been cancelled. Treatment descriphon including volumes used and hnal pressure 13 Prior to well operahon Subsequent to operation Representahve Daily Average Produchon or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 14. Attachments Da~ly Report of Well Operations [] Copies of Logs and Surveys Run [] 15 I hereby certifythat the foregoing ~s true and correct to the best of my knowledge S,gned/~/~/~.~.~ ~~ Title Production Superintendent Form 10-~4"Rev.-1~'-1-~5- -" - - - 0714c/SBBF Date"~, Ir-( Submit ~n Du March 6, 1987 State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99502 SUBJECT' SUBMITTAL OF APPLICATIONS FOR SUNDRY APPROVAL FOR MIBDLE GROUND SHOAL WELL NUMBER'S A 24-01 AND~~~ Gentlemen' Enclosed are two Applications for Sundry Approval for upcoming workovers on Middle Ground Shoal well numbers A 24-01 and A 33-14. The stimulation and reperforation on A 24-01 is scheduled to begin on March 12, 1987. The coil tubing unit acid treatment on A 33-14 is scheduled to begin March 13, 1987. Each Application is submitted in triplicate. For further information contact Susan Brown at (907) 263-9613. V~er~y tr~uly yours, Alask¢~ivision ~ Manag~ Regulatory Affairs SBB/kka Enclosures A, taska Oil & Gas Cons. Anchorage SBBE/aogcc.3 ... - STATE Of ALASKA I~ ALA , OIL AND GAS CONSERVATION CO .,SION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request. Abandon [] Suspend [] Operahon Shutdown [] Re-enter suspended well [] Alter casing [] T~me extension [] Change approved program [] Plugging [] Sbmulate I~ Pull tubing [] Amend order [] Perforate [] Other [] 2. Name of Operator Shell Western E&P Inc. 3 Address 601 West Fifth Ave., Suite 810, Anchorage, AK 99501 4 Locahon of well at surface Platform "A", Leg 4, Conductor 30 @ 1561'N & 385'W from SE corner of sec 11, T8N, R13W,S.M. At top of productive interval 9061' 3008'S & 1417'W from N.E. Corner Sec. 14, T8N, R13W, S.M. At effechve depth Attotaldepth(10,555') 3527'S & 1934'W from N.E. corner Sec. 14, T8N,R13W, S.M. 5. Datum elevation (DF or KB) 116' RKB feet 6. Unit or Property name Middle Ground Shoal 7 Well number A 33-14 8. Permit nur~b/er 67-~8 9. APl number 50-- 733-20057-00 10. Pool "G" Pool 11 Present well condition summary Total depth' measured true vertical 10,555' feet Plugs (measured) feet Effective depth measured true vertical 10,432 ' feet Junk (measured) feet Camng Structural Conductor Surface Intermediate Produchon L~ner Perforation depth Length S~ze Cemented 10,531', 7", 23-29#, N-80 Buttress, 1,476' 5" 18# N-80 Buttress measured 9,715' - 10,419' true vertical Tubing (size, grade and measured depth) 3-1/2", 9.2#, N-80 Buttress @ 8,949' Packers and SSSV (type and measured depth) PBR set ~, 8970' 12 Attachments Description summary of proposal [] Measured depth True Vertical depth 10,531' 8,956-10,432' 5 intervals Detailed operations program [] RECEIVED Alaska 0;] & Ga.S Cons Corn, mission BOP sketch ~ 13. Estimated date for commencing operation March 13, 1987 14. If proposal was verbally approved Name of approver Date approved 15 I hereby certify that the foreg,,o~ng is true and correct to the best of my knowledge Signed ~ .~"'.~~ ' Title Production Superintendent Commission Use Only Conditions of approval Notify commission so representahve may w~tness Approved by [] Plug integrity [] BOP Test [] Location clearance . , , Commissioner Form 10-403 Rev 12-1-85 FORMS/ROSWO. 1 I Approval No. ,/ .,.,/Z_/~ ~"/ by order of _.... i the commission Date.~ ~-;/~ ~'~ m Submit mn triplicate PROGNOSIS A33-14 OPERATION' CLEAN OUT Fe304 SCALE COVERING THE HR-HZ PERFORATION. ACIDIZE ALL INJECTION INTERVALS. TUBING- SEE ATTACHED COMPLETION EQUIPMENT DETAIL SHEET PERFORATIONS: SEE ATTACHED COMPLETION EQUIPMENT DETAIL SHEET STATUS- INJECTING ]]54 BWPD t 3]00 PSI 2/22/87 NOTE- FILL WAS ENCOUNTERED WITH SLICKLINE BAILER AT 10298' ON 2/08/8? AND IS COMPOSED OF IRON OXIDE. ACID RESUIREMENTS: 1000 GALLONS 15~ HC1 W/ INHIBITOR 1000 GALLONS 12% HCI/ 3% HF W/ INHIBITOR PROCEDURE' ].RU COILED TUBING UNIT AND PUMPING EQUIPMENT. RU TO TAKE RETURNS THROUGH CHOKE TO J-TUBE. SET UP SCREEN ON J-TUBE TO ALLOW MONITORING OF RETURNS AND RETENTION OF ANY RECOVERED SOLIDS. BULLET NOSE WASH NOZZLE IS TO BE SECURED TO ] 1/4" COILED TUBING WITH SWEDOE LOCK OR ALLEN SCREW CONNECTOR. WASH NOZZLE IS NOT TO BE THREADED ON DIRECTLY TO COILED TUBING. TEST ACID FOR STRENGTH BY TITRATION METHOD. PRESSURE TEST ALL SURFACE EQUIPMENT FROM THE PUMP DISCHAROE TO THE WELL HEAD TO 4200 PSI. 2. IF COILED TUBING CONTAINS DIESEL, FLUSH OUT TO PRODUCTION HEADER. MAINTAIN INJECTION PRESSURE ON COILED TUBING BY CONTINUING TO INJECT WHILE RIH. CLEAN OUT 3. LIGHTLY TAG FILL AT :10298' BEOIN TAKING RETURNS TO J- TUBE. CONTINUOUSLY MONITOR RETURNS. IF HYDROCARBON OR HZS ARE PRESENT, TAKE RETURN TO PRODUCTION HEADER. CLEAN OUT TO PBTD AT 10432' BY CIRCULATING AND DISSOLVING FILL WITH 500 GALLONS OF 15% HCL ACID. ALLOW WELL TO BACKFLOW TO AID IN REMOVAL OF DEBRIS. KEEP RECIPROCATING COILED TUBING. DO NOT ALLOW COILED TUBING TO REMAIN STATIONARY. AT PBTD, CIRCULATE/BACKFLOW AK ADDITIONAL lO0 BBL (CASING/TUBING VOLUME EXCLUDING CT) TO ENSURE FILL REMOVAL. AC I D JOB 4. SHUT IN RETURNS. MAXIMUM ALLOWABLE PUMP PRESSURE IS 4200 PSI. WITH END OF COILED TUBING AT 10419' PUMP 250 GALLONS 154 HCL, 1000 GALLONS 124 HCL/ 3% HF, AND 250 GALLONS ]5% HCL AT 0.5 GPM. WHEN ACID REACHES THE EOT MOVE COIL UP AT 70 FPM TO 9715'. WHEN MUD ACID REACHE~ EOT, MOVE DOWN TO ]0419' MOVE END OF TUBING BETWEEN 10419' AND 9715' UNTIL ALL ACID IS DISPLACED INTO FORMATION. CONTINUE INJECTING WHILE POH. RD. COMPLETION EQUIPMENT DETAIL SHEET #GS A33-14 1/30/87 NO. ITEM _ APPROXIMATE TVD. ND. 1. OTIS "X" NIPPLE 2. OTIS "X" NIPPLE 3. TIN LOCATOR 4. TIN TIE-BACK SLEEVE 5. TIN TYPE S PACKER 6. TIW 20' PBR w/SEALS 32! 8949 8952 8956 896] 89?0 CASING ?" 23#, N-80 BUTTRESS ~ 0 - 6500' 26#,'~ 6500 - g900' 29#, ~ 9900 - 10531' 5" 18#, N-80 BUTTRESS (LINER) ~ 8956 - 10432' PBTD = 10,432' TD = 10,555' TUBING 3 1/2", 9.2#, N-80 BUTTRESS 8 8949' PERFORATED ZONE · GROSS INTERVAL HC-HD HK-HN HN-HR lIN-HR HR-HZ 9715-9804' 10060-10162' 10162-10239' 10260-10302' 10328-10419' { R E C E ! ~ ~ D SCHLUMBERGER OFFSHORE SERVICES A Division of Schlumberger Limited JAN 0 1,987 January 27, 1987 Oil & Gas Co~s Co Anchorage Shell Western E&P, Inc. 601W. Fifth Avenuep Suite 810 Anchoragep AK 99501 Atl~ffkm: Hr Joe Fram Enclosed--6-~i~.rin~ofthe Production Log (Trpcer-ll/21/86) Cornpm~ SVEPI ,Well Hiddle Ground Shoal "A" #3~-14 F~ Middle Ground Shoal ,Coun~ Kenai State Alaska P. O. Box 1001 Kenai, AK 99611 Attention: Shelley Ramsey Additiormlprin~ are beingsentto: I BL nrin~, original film ShellrWestern E&P~ Inc. P. O. Box 527 Houston, TX 77001 Attn: LoR Files~ liCK 4,147 I BL prints, I Reverse Folded Sepia State of Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK ,,,99~01 ArCh: H. ~. Kugler I BL ints Shell Western E&P~ Inc. P. O. Box 527 Houston, TX 77001 Attn: R. J. Vallejo~ WCK 113~ I BL prin~ Shell Platform "A" c/o Shell Kenai Office North Star Rou~e ~1 P. 0. ~OX 485 Wik Road K~nai, AK 99611 1 BL r~rints , I Hylar ARCO ~laska, . P. O. BOx 100360 Anchorage, AK 99501 Attn: H. F. Blacker 2 BL nrin~ ' 2 Reverse Roiled Sepia Chevrbn U.S.A., Inc. P. O. Box 107839 Anchorage, AK 99510 Attn: ~. L. ~eaver prints PLEASE SIGN AND RETURN ONE COPY OF THIS TRANSHITTAL. The film is returned to Shell~ Houston. We appreciate the privilege of serving you. prints Very truly yours, SCHLUMBERGER OFFSHORE SERVICES Roger H. Theis DISTRICT MANAGER ( SCHLUMBERGER OFFSHORE SERVICES A Division of Schlumberger Limited HOUSTON. TEXAS 77001 JUNE 7,1985 SHELL WESTERN E&P INC. P.O. BOX 527 HOUSTON, TX. 77001 Attention: LOG FILES,.. WCK 4147 PLEASE REPLY TO Po r RD. ANCHORAGE, ALASKA 99502 ATTN: BETH CUZZORT Gentlemen: Enclosed are .1EL prints of the PROI~IICTI Company SHELL WESTERN E&P INC. , Well. [~GS A 33-14 Field MIDDLE GROUND SHOAL ., County KENAI ~tat~ ALASKA ,. - Additional prints are being sent to: 1BL nrints SHEL~ WESTERN E&P INC. P.O. BOX 527 HOUSTON~ TX. 77001 ATTN' BRIAN TEPPER,WCK 1128 2EL nrints SHELL WESTERN E&P INC. 601W.FIFTH AVE;SUITE 810 ANCHORAGE~ ALASKA 99501 ATTN: TIM PUTNAM 1MYLAR 1EL nrints ARCO ALASKA INC. P.O. BOX 100360 ANCHORAGE, ALASKA 99501 ATTN: JOHN C. HAVARD on: SEPt~" 1] OF A ASK . Olt. & GAS CONSERVA~ION COMM. PORCUPINE DR. CHORAGE, ALASKA 9950.1/ H.W KUGLER 1EL nrints SHELL' PLATFORM "A" OR "C" ~O SHELL KENAI OFFICE NORTH STAR ROUTE P.O. BOX 485 WIK RD. KENAI., ALASKA 99611 ~.prints 1RROLLED SEPIA P.O. BOX 107839 ANCHOI~JiGE, "ALASKA 99510 'ATTN: J.L. WEAVER The film is RETURNED TO SHELL We appreciate the privilege of serving you. prints ' DATE: "~ Very truly yours, SCHLUmbERGER OFFSHORE D_AV! O REBOL OI S'l'l~ ICT MANAGER SCHLUMBERGER OFFSHORE SERVICES A D,ws~on of Schlumberger Limited HOUSTON. TEXAS 77001 November 7, 1984 Shell Oil Company 601W. Fzfth, Suite 810 Anchorage~ AK 99501 Attention Mr. Tim Putnam iREPLY TO ~.( ~'r~,~oOoR{ SERV,C£S Kenai, AK 99611 Attention: Shelley Ramsey Gentlemen' Enclosed ore2BL printsofthe Run 1-2"&5" GR/CCL~ Run 2-5" GR/CCL Company Shell Oil Company ,Well Middle Ground Shoal "A" 33-14 Field iMiddle Ground Shoal ,Coun~ Kenai State AK on' Additionolprintsare being sentto: 2 BL prints plus original films Shell Western E&P, Inc. P. O. Box 527 Houston, TX 77001 Attn: Log Files, 4147 WCK 3 BL prints Shell Western E&P, Inc. P. O. Box 327 Houston, TX 77001 Attn: Brian Tepper, WCK 1128 .ded Sepia ~!%~Hg!g,~!~eKi~ni Commission prints 1BL prints and 1 Mylar ARCO Alaska, Inc. P. 0. Box 100360 Anchorage, AK 99501 Attn: John C. Havard prints 1BLprlnts and 1 Mylar and 1 Reverse Rolled Sepia prints Chevron U.S.A., Inc. P. O. Box 107839 Anchorage, AK 99510 Attn:. J. L. Weaver The film is returned to Shell- Houston Log Files We appreciate the privilege of serving you. RECEIVF~D BY:. ~ ~,TP F ~'~ AlasKa 01t & Gas Cons. Anchorage Ve~ truly yours, SCHLUMBERGER OFFSHORE SERVICES $OS--! 565- A David N. Rebol ~ DISTRICT MANAGER 'A STATE OF ALASKA ALAS OIL AND GAS CONSERVATION'L;OMMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1 DRILLING WELL [] COMPLETED WELL Injector 2 Name of Operator Shell Western E&P, Inc. 3 Address ATTN Production Superintendent. 601 W. 5th Ave., #810, Anchorage, AK 9950! 4 Location of Well Conductor 30, Leg 4 @ 65.88' S. & 49.28' @ 1627' N. to 435' W. from SE Corner Sec. S.M. E. from Leg 1 11, T8N, R13W, 5 Elevat,on ,n feet (indicate KB, DF, etc ) 116' D. F. 12 Lease Designation and Serial No ADL 18756 7 Permit No 67-68 8 APl Number 5o.- .733-20057-00 9 Unit or Lease Name MGS 10. Well Number A 33-14 11 F,eld and Pool Middle Ground Shoal "G" Pool Check Appropriate Box To Indicate Nature of Not,ce, Report, or Other Data NOTICE OF INTENTION TO SUBSEQUENT REPORT OF. (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations [] St,mulate [] Abandon [] Stimulatmon [] Repair Well [] Change Plans [] Repairs Made {~ Pull Tubing [] Other [] Pulling Tub,ng ~ (Note Rel3ort multiple completions on Form 10-407 with a submitted Form 10-407 for each completion ) OTHER [] Altering Casing [] Abandonment [] Other [] 13 Descrmbe Proposed or Completed Operations (Clearly state all pertinent detads and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25 105-170) See attached. RECEIVED Alaska Oil & Gas Cons. Commission Anchorage 14 I hereby certify that,~he fo.~egolng is true and correct to the best of my knowledge Date 8/7/84 Conditions of Approval, ,f any By Order of Approved by__ COMMISSIONER the Commission Date Form 10403 Rev 7-1-80 Subm,t "Intentions" in Trlphcate and "Subsequent Reports" in Dupl,cate MGS A33-14 ~j~ 4/27/84 - 4/29/84 ~ INSTALLED BOP RISER A~ FLOWLINE, TESTED BOP. RU/OIALOG AND R~N 2 3/4" GAUGE RING IN TBG TO 8946'. CUT TBG @ 89' WITH 2 5/8" JET JET CUTTER. ATTEMPTED TO PULL TBG. DROPPED HANGAR & TBG BACK INTO WELLHEAD. RECOVERED ALL PIECES OF BROKEN GRAPPLE. CUT TBG @ 2015' & LAID DOWN TBG. RIH W/OVERSHOT TO TOP OF FISH @ 2015'. MILLED. TBG PARTED @ PREVIOUS SHOT @ 8905'. LAID DOWN TBG/CONTROL LINE & BALL VALVE NIPPLE. TBG STRING FULL OF HOLMS. RIH WITH OVERSHOT. UNABLE TO REACH TOP OF FISH ~ 8905'. RIH W/6" MILL & CSG SCRAPER. UNABLE TO CIRC. WASHED 40' TO TOP OF FISH @ 8905'. 4/30/84 CIRC HOLE CLEA~N W/SEAWATER. WASHED OVER TBG FROM 8905' TO 8991'. TBG CSG ANNULUS PACKED WITH SAND. TAGGED TOP OF PACKER 8991'. 5/ 1/84 - 5/ 2/84 FISHED. RECOVERED 28 JTS TBG, SLIDING SLEEVE, PKR, ONE SIDE POCKEI MANDREL & TBG CUTOFF. TBG BETWEEN TOP PKR AND ~2 PKR WAS FULL OF HOLES & TBG PARTED APPROX. 7' ABOVE SLIDING SLEEVE IMMEDIATELY ABOVE #2 PKR. CIRC 75 BBLS SWEEP & SPOTTED 75 BBLS PILL ON TOP OF PKR. JARRED ON FISH. RECOVERED SLIDING SLEEVE, PKR & 24' OF JT BELOW PKR. CSG INSPECTION LOG INDICATED HOLE @ 6342'. MODERATE TO SEVERE CORROSION BEGINNING @ TOP OF 26# CSG. CALIPER INDICATED~ 55-60%REMAINING WALL THICKNESS WITH DECREASING WALL THICKNESS TO ~ PERFS @ 9715-9804'. 25-35% REMAINING WALL AT 7750' & 8945'. WASHED OVER FISH TO REMAINING PKR WHICH HAD FALLEN TO BOTTOM. 5/ 3/84 - 5/ 6/84 CONTINUED TO FISH. 5/ 7/84 - 5/19/84 RECOVE~-ED PKR #3. FISHED. 5/20/84 RECOVERED PKR #4 & ALL TBG EXCEPT FOR 27' OF TBG. TAGGED FILL ~ 10287'. DRILLED Finn & BRIDGES IN CSG FROM 10287-10432'. 5/21/84 RIH W/CSG SCRAPER TO 10432'. CIRC CLEAN. RAN DIALOG CSG CALIPER/ INSPECTION LOG. CONDITION OF CSG SAME AS FIRST INSPECIION LOG. RAN GR/CCL FROM 10432-6000'. RIH W/BAKER CMT RETAINER & SET ~ 9593'. TESTED LINES & ESTABLISHED INJ RATE 5 BPM @ 1750 PSI. MIXED & PUMPED 250 S× "G" CMT W/ .3% D-31, .75% D-19, .2~ D-6 AND 5 GAL/lO0 SX R12L. · SLURRY WI 15.5 PPG 1.14 CU.FT./SX. DISPLACED W/FILTERED SEAWATER. FINAL DISPLACEMENT PRESSURE 200 PSI @ 2 BPM. FINAL SHUT IN PRESSURE 145o PSI. cIP. 5/22/84 SET BAKER MODEL "C" RETRIEVABLE BRIDGE PLUG @ 9000' & RETRIEVAM~TIC S0UEEZE TOOL @ 6400'. TESTED CSG TO 1000 PSI. SPOTTED 3 SX SA.ND TO PROTECT MODEL "C" BRIDGE PLUG. RESET SQUEEZE PKR @ 6150' & TESTED CSG TO SURFACE W/1000 PSI. OPEN 9 $/8" X 7" ANNULUS. ATTEMPTED TO ESIAB- LISH CIRC. NO RETURNS IN ANNULUS. PUMPED INTO ANNULUS @ 3 BPM 1000 PSI. MIXED 200 SX "G" CMT W/ .3% D-31, .75~ D-19, & .2% D-6. SLURRY WT. 15.8. DISPLACED CMT W/49 BBLS FILTERED SEAWATER. MAINTAINED 1000 PSI ON BACKSIDE. GRADUALLY DECREASED DISPLACEMENT RATE TO 1BPM. FINAL SQUEEZE PRESSURE 1050 PSI. CIP. 5/23/84 WOC. POH W/BAKER RETRIEVAMATIC. TAGGED CMT @ 6258'. CLEANED OUT CMT TO BELOW HOLE IN CSG @ 6340'. TESTED CSG TO 1000 PSI. RIH TO 9000'. WASHED TO BRIDGE PLUG. CIRC. HEC SWEPT AROUND. POOH W/BRIDGE PLUG. 5/24/84 LAID DOWN BAKER MODEL "C" BRIDGE PLUG. RIH WITH FLAT BOTTOM JUNK MILL TO DRILL UP CMT RETAINER @ 9593'. TAGGED CMT @ 9568'. CLEANED OUT CMT TO 9634'. 5/25/84 FINISHED CLEANING OUT CMT TO 10432'. CIRC HOLE CLEAN & PUMPED AROUND HEC SWEEP. RU & RAN 37 JTS. 5", 18~ N-80 SFJP CSG. SHOE @ 10432 10429'. COLLAR ~0396-10394'. LANDING COLLAR 1 6-10355'. HANGER 8994-8989'. PBR 8989-8970'. PACKER/TIE BACK 8970-8955'. CIRC & CMT W/150 SX "G" CMT BLENDED W/ .3% D-31, .75% D-19, .2% D-6, 2.5 GAL/ 100 SX R12L DISPLACED W/86.5 BBLS SEAWATER. CIP CIRC OUI EXCESS CMI. 5/26/84 LAID DOWN LINER SETTING TOOL. RIH TO TOP OF LINER. CLEANED OUT LAND- ING COLL', FLOAT COLLAR & GOOD CMT TO SHOE. CIRC CLEAN W/HEC SWEEP. 5/27/84 RIH W/PBR POLISH MILL. DRESSED PBR 8989-8970' C.B.U. RAN GR/CCL 10419-6000. RIH WITH GUNS. PERFED 10419-10328, 10302-10260, 10239- 10060, 9804-9715. FLOWED DIESEL BACK THROUGH TESI SEPARATOR. FLOWED WATER TO CLEAN UP. 5/28/84 FLOWED DIESEL FROM TBG TO TEST SEPARATOR FOR 8 HOURS. GUNS STUCK IN LINER. FISHED. LAID DOWN BAKER GUNS. ALL SHOTS FIRED. RIH CLEANED OUT 5" LINER. CIRC OUT. PUMPED AROUND HEC SWEEP. 5/29/84 PRESSURE TESTED ALL CONNECTIONS TO 3000 PSI. DISPLACED ANNULUS WITH WATER INHIBITED W/ 7 GAL Q79F BACTERIACIDE INHIBITOR, 7 GAL K520 OXYGEN SCAVENGER, 5 GAL KWF-12 CORROSION INHIBITOR. INSTALL CAMERON 10" EX- TENDED NECK TBG HANGER. LANDED TBG AND INSTALLED BACK PRESSURE VALVE. ND BOP STACK. 5/30/84 REMOVED BOP STACK AND CAMERON RISER. INSTALLED CAMERON COMPACT WELL HEAD, TEST TREE. PREPARED TO MOVE RIG AND RETURN TO INJECTION. 6/15/84 RETURNED TO INJECTION RECEIVED AUG 1 ,.~.: ~, b~s Cons Commission STATE OF ALASKA ALAS_I~ OIL AND GAS CONSERVATION~ )MMISSION SUNDRY NOTICES AND REPORTS ON WELLS DRILLING WELL [] COMPLETED WELL Injector 2 Name of Operator Shell Western E&P, Inc. 3 Address ATTN Production Superintendent 601 W. 5th Ave., #810, Anchorage, AK 99501 4 Location of Well 7 Permit No 67-68 8 APl Number 50- 733-20057-00 9. Umt or Lease Name MGS Conductor 30, Leg 4 @ 65.88' S. & 49.28' E. from Leg 1 @ 1627' N. to 435' W. from SE Corner Sec. 11, T8N, R13W, S.M. OTHER 5 Elevat,on in feet (indicate KB, DF, etc.) 116' D. F. 12 10 Well Number A 33-14 11 Field and Pool Midd]e Ground Shoa] 6 Lease Designation and Serial No "G" POD] ADL 18756 Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO SUBSEQUENT REPORT OF (Submit in Duplicate) [] Altering Casing [] Abandonment [] Other (Submit in Trlphcate) Perforate [] Alter Casing [] Perforations Stimulate [] Abandon [] Stimulation Repair Well [] Change Plans E] Repairs Made Pull Tubing [] Other [] Pulling Tubing (Note Report multiple completions on Form 10-407 w~th a submitted Form 10-407 for each completion ) 13 Describe Proposed or Completed Operations (Clearly state all pertinent detads and g~ve pertinent dates, ~nclud~ng estimated date of starting any proposed work, for Abandonment see 20 AAC 25 105-170) See attached. RECEIVED AUG 1 3198~ ~3~1 C, ~,~s Cons. Commission A:l~.h0rage 14 I hereby certify that th~golng is true and correct to the best of my knowledge Signed V I ~ ~ ""' .__ ~ The spacc~dw for Comm,sslon use -- Date 8/7/84 Conditions of Approval, if any By Order of Approved by COMMISSIONER the Commlss,on Date ~ Submit "Intentions" ~,l Triplicate Form 10-403 Rev 7-1 and "Subsequent Reports" in Duplicate MGS A33-14 4/27/84 - 4/29/84 INSTALLED BOP RISER AND FLOWLINE, TESTED BOP. RU DIALOG AND RAN 2 3/4" GAUGE RING IN TBG TO 8946'. CUT TBG @ 89' WITH 2 5/8" JET JET CUTTER. ATTEMPTED TO PULL TBG. DROPPED HANGAR & TBG BACK INTO WELLHEAD. RECOVERED ALL PIECES OF BROKEN GRAPPLE. CUT TBG @ 2015' & LAID DOWN TBG. NIH W/OVERSHOT TO TOP OF FISH @ 2015'. MILLED. TBG PARTED @ PREVIOUS SHOT @ 8905'. LAID DOWN TBG/CONTROL LINE & BALL VALVE NIPPLE. TBG STRING FULL OF HOLES. NIH WITH OVERSHOT. UNABLE TO REACH TOP OF FISH @ 8905'. NIH W/6" MILL & CSG SCRAPER. UNABLE TO CIRC. WASHED 40' TO TOP OF FISH @ 8905'. 4/30/84 CIRC HOnE CLEA3q W/SEAWATER. WASHED OVER TBG FROM 8905' TO 8991'. TBG CSG ANNULUS PACKED WITH SAND. TAGGED TOP OF PACKER 8991'. 5/ 1/84 - 5/ 2/84 FISHED. RECOVERED 28 JTS TBG, SLIDING SLEEVE, PKR, ONE SIDE POCKET MANDREL & TBG CUTOFF. TBG BETWEEN TOP PKR AND ~2 PKR WAS FULL OF HOLES & TBG PARTED APPROX. 7' A~OVE SLIDING SLEEVE IM3~EDIATELY ABOVE #2 PKR. CIRC 75 BBLS SWEEP & SPOTTED 75 BBLS PILL ON TOP OF PKR. 3ARRED ON FISH. RECOVERED SLIDING SLEEVE, PKA & 24' OF JT BELOW PKR. CSG INSPECTION LOG INDICATED HOLE @ 6342'. MODERATE TO SEVERE CORROSION BEGINNING @ TOP OF 26~ CSG. CALIPER INDICATED 55-60%REMAINING WALL THICKNESS WITH DECREASING WALL THICKNESS TO~ PERFS ~ 9715-9804'. 25-35% REMAINING WALL AT 7750' & 8945'. WASHED OVER FISH TO REMAINING PKR WHICH HAD FALLEN TO BOTTOM. 51 3184 - 51 6~84 CONTINUED TO FISH. 51 7184 - 5119184 RECOVERED PKR #3. FISHED. 5/20/84 RECOVERED PKR #4 & ALL TBG EXCEPT FOR 27' OF TBG. TAGGED FILL 10287'. DRILLED FILL & BRIDGES IN CSG FROM 10287-10432'. 5/21/84 NIH W/CSG SCRAPER TO 10432'. CIRC CLEA~N. RAN DIALOG CSG CALIPER/ INSPECTION LOG. CONDITION OF CSG SAME AS FIRST INSPECIION LOG. RA~ GR/CCL FROM 10432-6000'. RIH W/BAKER CMT RETAINER & SET ~ 9593'. TESTED LINES & ESTABLISHED INJ RATE 5 BPM @ 1750 PSI. MIXED & PUMPED 250 SX "G" CMT W/ .3% D-31, .75% D-19, .2~ I)-6 AND 5 GAL/lO0 SX R12L. . SLURRY WT 15.5 PPG 1.14 CU.FT./SX. DISPLACED W/FILTERED SEAWATER. FINAL DISPLACEMENI PRESSURE 200 PSI @ 2 BPM. FINAL SHUT IN PRESSURE 1450 PSI. CIP. 5/22/84 SET BAKER MODEL "C" RETRIEVABLE BRIDGE PLUG @ 9000' & RETRIEVAM~TIC SQUEEZE TOOL @ 6400'. TESTED CSG TO 1000 PSI. SPOTTED 3 SX SAND TO PROIECT MODEL "C" BRIDGE PLUG. RESET SQUEEZE PKR @ 6150' & TESTED CSG TO SURFACE W/1000 PSI. OPEN 9 5/8" X 7" ANNULUS. ATTEMPTED TO ESTAB- LISH CIRC. NO RETURNS IN ANNULUS. PUMPED INTO ANNULUS ~ 3 BPM 1000 PSI. MIXED 200 SX "G" CMT W/ .3% D-31, .75% D-19, & .2% I)-6. SLURRY WI. 15.8. DISPLACED CHI W/49 BBLS FILTERED SEAWATER. MAINTAINED ]000 PSI ON BACKSIDE. GRADUALLY DECREASED DISPLACEMENI RATE TO 1 BPM. FINAL SQUEEZE PRESSURE 1050 PSI. CIP. 5/23/84 WOC. POH W/BAKER RETRIEVTdiATIC. TAGGED CMT @ 6258'. CLEANED OUT CMT TO BELOW HOLE IN CSG @ 6340'. TESTED CSG TO 1000 PSI. RIH TO 9000'. WASHED TO BRIDGE PLUG. CIRC. HEC SWEPT AROUND. POOH W/BRIDGE PLUG. 5/24/84 LAID DOWN BAKER MODEL "C" BRIDGE PLUG. RIH WITH FLAT BOTTOM JUNK MILL TO DRILL UP CMT RETAINER ~ 9593'. TAGGED CHI @ 9568'. CLEANED OUT CMT TO 9634'. 5/25/84 FINISHED CLEANING OUT CMT TO 10432'. CIRC HOLE CLEAN & PUMPED AROUND HEC SWEEP. RU & RAN 37 JTS. 5", 18# N-80 SFJP CSG. SHOE @ 10432 ND BOP STACK. 5/30/84 REMOVED BOP STACK AND CAMERON RISER. INSTALLED CAMERON COMPACI WELL HEAD, TEST TREE. PREPARED TO MOVE RIG AND RETURN TO INJECTION. 6/15/84 RETURNED TO INJECTION t~ STATE OF ALASKA O~' ALASKA IL AND GAS CONSERVATION C vIMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1 DRILLING WELL [] COMPLETED WELL OTHER [] Injector 2 Name of Operator Shell Western E&P, Inc. 3 Address Attention Wayne Simpson 601 W. 5th Avenue, Suite 810, Anchorage, Alaska 99501 4 Location of Well Conductor 30, Leg 4 @ 65.88' S. & 49.28' E. from Leg 1 @ 1627' N. to 435' W. from.SE Corner Sec. ll, T8N, R13W, S.M. 5 Elevation ~n feet (md~cate KB. DF, etc ) 116' D.F. Lease Designation and Serial No ADL 18756 7 Permit No 67-68 8 APl Number 50- 733-20057-00 9 Unit or Lease Name HGS 10 Well Number A 33-14 11 F~eld and Pool Middle Ground Shoal mmG" Pool 12 Check Appropriate Box To Indicate Nature of Not~ce, Report, or Other Data NOTICE OF INTENTION TO /-I"fl~lr/_~/)~p~z)/~ SUBSEQUENT REPORT OF (Submit ,n Triplicate) [I .~_ .~ ?..~~'~ ---- (Submit in Duplicate) Perforate j~ Alter Cas,ng i~ Perforations ~' Alter,ng Cas,ng Stimulate [] Abandon [] Stimulation [] Abandonment Repair Well [] Change Plans [] Repairs Made [] Other Pull Tubing [] Other [] Pulhng Tubing [] (Note Report multiple completions on Form 10-407 w~th a submitted Form 10-407 for each completion ) 13 Describe Proposed or Completed Operations (Clearly state all pertinent detads and g~ve pertinent dates. ~ncludmg estimated date of starting any proposed work, for Abandonment see 20 AAC 25 105-170) See Attached RECEIVED MAY 2 }984 Alaska Od & 14 I hereby certify that the foregoing ~s true and correct to the best of my knowledge Signed ~'//~~, .4~_ /~/~ Title Division Production Superintenc~f~t The space belOV~,~or use Commission 5/22/84 Conditions of Approval, ~f any ~pproved by ~m 10-403 7-1-80 IIRIGINAI. SIGIIE8 B! LONNIE C. SIlllTll Approved Copy I~turn~l _., z By Order of COMMISSIONER the Commission Submit "Intentions" ~n Triplicate and "Subsequent Reports" ~n Duplicate A33-14 Middle Ground Shoal OPERATION: Squeeze cement zones HC-HZ and repair casing leak at 6340+. Procedure: . After injection tubing and packer are recovered, TIH with drill bit and casing scraper. Clean out casing to PBTD at 10,460+. Circulate hole clean. If necessary, sweep hole with HEC pill. TOH. 2. RU wireline. Run gauge ring from surface to 9600+_. ® . RIH with 7" Baker Model K-1 cement retainer {or equivalent} and set at 9600_+. RD wi reline. . - TIH with stinger sub on drill pipe and sting into retainer. Establish an injection rate of at least I BPM at a maximum pressure of 3500 psi. 5. Mix 200 sx of Class G cement with a fluid loss not to exceed 60 cc/30min and a set time of 4 hours at 150°F. Pump at a maximum rate of 2 BPM and a pressure not to exceed 1600 psi with all cement in tubing. Final squeeze pressure is 2000 psi. If squeeze is obtained, circulate out excess cement. If squeeze is not obtained, displace cement to retainer and sting out. TOH. ® TIH with 7" retrievable bridge plug and cementing packer. Set RBP at 9000+. Test casing at 1000 psi to known casing leak at 6340+-. If there is no casing leak below 6340+_, retrieve bridge plug and set at 6450+-. Cap with 3sx of sand. Test to 2000 psi. Set cementing packer at 6200 and test casing to 1000 psi above 1 eak. TOH. RIH with cement retainer and set at 6200. Pressure backside to 1000 psi and monitor throughout job. There is no cement behind casing at 6340. No squeeze is expected. A 1000' plug will be circulated behind pipe. Open bradenhead and monitor pressure and flow. Mix 200 sx of Class G cement as above. Pump at 2 BPM and a pressure not to exceed 1000 psi with all cement in tubing. With 100 sx displaced below retainer, close bradenhead. When all cement is displaced to retainer, sting out. TOH. SD 24 hours. 9, TIH with 6-1/8" bit and collars and clean out cement. Test squeeze at 1000 psi for 15 minutes. If squeeze doe.s not hold consult Houston and resqueeze. TOH. ¢' 10. TIH with retrieving head and recover RBP. TOH. 11. 'FIH with 6-1/8" bit and collars. Drill and clean out to PBTD at 10,460+. Circulate hole clean. TOH RUN 5" LINER Line~ will be cemented with 120 sx of Class G cement with a thickening time of 4 hours at 140°F. Have sample of cement tested by B. J. Hughes using Cook Inlet water before operation begins. Maximum setting depth 9000'. 12. When hole is clean, run liner as follows (drawing attached): Liner Shoe 30' 5" 18# SFJP Liner Landing Collar 1400' 5" 18# SFJP Liner 20' PBR Liner Hanger Liner packer w/tieback receptacle Setting Tool NOTE: Keep liner filled while RIH. Extreme care should be exercised wh--~-~Te installing liner wiper plug on polished extension nipple of setting tool. Record weight of liner on weight indicator. Rabbit each joint of drillpipe going in hole. If restriction exists, lay down joint. Keep pipe filled. While pipe is being run, install pump down plug in cementing manifold. Make up manifold on joint of pipe. 13. When liner is about I joint from PBTD, make up manifold, ball dropping sub and swivel on top of setting string. 14. Attempt to rJciprocate liner. If possible, reciprocate while cementing. Establis~i an injection rate with water. 15. Mix and pump 120 sx Class G cement. 16. Clean lines and pump. Release ball and pump down plug. 17. Continue to reciprocate liner and displace cement. Slow pumps down as pump down plug reaches liner wiper pl. ug. A 1000 psi increase is expected when pump down plug seats in wiper plug. Record pump pressure, rate and time while displacing cement. ¢ 12ECEf VED 18. Continue to reciprocate until ball seats in Landing Col m~ will cause a rapid increase in pump pressure. ~oF~J'~ - 19. Shut down pump, release pressure and position liner with top no lower than go00. 20. Pressure up until small drop in pressure occurs indicating hanger 'is set. To confirm, slack off until liner weight plus 5000# is on hanger. Liner is now set. 21. Pressure up to shear out ball seat. Continue pumping until wiper plug lands. Test plug to 1000 psi above circulating pressure. 22. Set rotary slips leaving 30,000# on swivel and cementing manifold. 23. Rotate to right 8 turns, check for torque. Continue to rotate to right 20 torque free turns. 24. Pick up 5' to position setting dogs for packer. Note loss of liner weight. 25. Slack off 1' or 20,000#, repeat several times to insure packer setting. 26. Remove setting tool from liner and reverse out an.y excess cement. 27. TOH setting string. NOTE: If setting tool can not be released from liner, pressure up on liner wiper plug and shear out shear relief sub. Reverse circulate out cement above sub. 28. SD for 12 hours. 29. TIH with 4-1/8" bit, casing scraper, 1500' 2-3/8" tubing and drill pipe. Clean out to float collar. Reverse circulate well clean. TOH. 30. TIH with 4-7/32" polishing mill and dress PBR. Circulate HEC pill to insure hole clean. TOH. 31. RU wireline and run CCL/Gamma Ray from PBTD to 8500'-+. RD' wireline. Correlate log with REFERENCE LOG - SWS Dual Induction - Laterlog 11-30-67. 32. Make up 3-3/8" 4JSPF tubing conveyed gun so that the following zones will be perforated with the seals in liner PBR. NOLTE: (Top of bottom zone onlj~ will be able to be perforated): ALL DEPTHS BASED ON REFERENCE LOG ' 9715- 9804 10,060. 10,239 '10,261 . 10,302 10,328 . 10,460 [or' PBTD), 33. Strap 3-1/2" 1t-80 tubing into hole. 34. Tag up on PBR and measure for space out. test/firing head. Space out and assemble 35. Sting out of PBR and displace tubing with diesel. 36. Sting into PBR. Fire gun by dropping detonator bar. If possible flow diesel to production separator and allow well to clean up. -- 37. TOH perforating gun and lay down. Redress seals. 38. TIH with injection string consisting of seating nipple, seals and 3.5" 9.3# N-80 tubing. 39. Fill casing-tubing annulus with 250bbl inhibited fresh water. 40. Seat seals with 10 point slack off. Return to injection. DATE:~ RECEIVED MAY 2 £ Lq 4 Alaska Oil & g~s Cons. Commission Anchorage : ! : ! I · ! ( STATE OF ALASKA O(0 ALASKA OIL AND GAS CONSERVATION MMI$$1ON SUNDRY NOTICES AND REPORTS ON WELLS I DRILLING WELL [] COMPLETED WELL [~ Injector 2 Name of Operator Shell Western E&P, Inc. 3 Address Attn: Wayne Simpson 601 W. 5th St., #810, Anchorage, AK 99501 4 Locatmon of Well Conductor 30, Leg 4 @ 65.88' S. & 49.28' E. from Leg 1 @ 1627' N. to 435' W. from SE Corner Sec. 11, T8N, R13W, S.H. 5 Elevation in feet (mdmcate KB, DF, etc ) 116' D.F. Lease Designation and Serial No ADL 18756 OTHER [] 7 Permit No 67-68 8 APl Number s0- 733-20057-00 9 Unmt or Lease Name MGS 10 Well Number A 33-14 11 F~eld and Pool Middle Ground Shoal "G" Pool 12 Check Appropriate Box To Indmate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO. (Submit m Tnplmate) Perforate [] Alter Casmg [] Perforations Stimulate [] Abandon [] Stimulation Repair Well [~ Change Plans [] Repairs Made Pull Tubing [~ Other [] Pulling Tubing (Note Reportmuluplecomplet~onson Form 10-407w~thasubm~tted Form 10-407 for eachcompletmn) SUBSEQUENT REPORT OF (Submit m Duplmate) [] Altering Casing [] Abandonment [] Other 13 Describe Proposed or Completed Operations (Clearly state all perunent details and give pertinent dates, mcludmg estimated date of starting any proposed work, for Abandonment see 20 AAC 25 105-170) See Attached. Su~bsequent Work Reported o. rage 14 I hereby c that ' fore in ~s e nd orrect to the best of my knowledge :!.? Title Div. Prod. Adm. Mqr. S~gned The space below for Commission use Date 4/5/84 Conditions of Approval, if any Approved by COMMISSIONER Approved Copy Re.tu~ed By Order of the Commission Date Subm~t"ln(ent~ons ~nTnphcate Form 10-403 Rev 7-1-80 and "Subsequent Reports" ~n Duplicate Status Workove~ Prognosis A33-14 W. H. Room #4 Conductor #30 Platform A Middle Ground Shoal Field Water injection well shut in. Probable holes in tubing below hanger and holes in casing at +6300'. Objective: Pull Tubing. Pull packers. Repair casing. Obtain injection profile. Run new tubing - packer string. Return well to normal injection. Procedure: . . Have enough mud available on board to kill well if necessary. Killing the well before the location of casing holes is determined and repaired will most likely not be possible. Back flow well overboard during workover operations. If returns contain oil, flow into deck tanks. Monitor returns for H2S. Set B.P.V. in tubing hanger. Nipple down tree. Nipple up B.O.P. Test B.O.P. to 3500 PSI. Pull bind on tubing. If packers do not pull loose (most likely the case) R.I.H. with jet tubin_c cutter. Cut tubing at 8960'. P.O.O.H. and lay down tubing. Fish packers as needed. . . ® R.I.H. with bit and scraper to top of junk at 10,460'. P.O.O.H. Rig up dialog. Run casing caliper log from top of fish to surface. Identify locations of holes and general casing condition. R.I.H. with Baker Model "C" retrievable bridge plug - packer assembly. Set bridge plug at 8930'. Pull up hole +20' and set packer. Pressure up on tubing to 3500 psi to test plug. Release pressure and packer. Continue testing casing with retrievable packer until holes are located. Obtain positive casing tests above and below damaged area. P.O.O.H. NOTE: If holes are less than 2500', a supplemental prognosis will be supplied to retrieve casing to below the holes and stab into existing casing with a new string. If holes are less than 1000' above retrievable bridge plug, spot and tag 100' of sand on top of plug before proceeding. R]I.H. with Baker Model "K-I" cement retainer and set 1000' above holes in casing. Test annulus to 3500. Obtain formation and squeeze rate. · ..... . Pump 10 bbls. of fresh water followed by 200 cu. ft. Class "G" cement with 2% CaC1 (accelerator), .3% HAL 22A (fluid loss additive), and 20 gal/lO0 sks CFR2L (friction reducer). Follow cement by 10 bbls. fresh water. NOTE: Check cement mixtures for set-up time and compatibility with platform water before pumping. Above mixture is for expected squeeze at _+6000'. Different squeeze locations will require changing cement mixtures for proper pumping time. When cement reaches holes, pump at +1 BPM and attempt running squeeze. Begin hesitation squeeze when cement top is 300' above holes. If squeeze is not obtained, over-displace, W.O.C., and repeat step ?. If squeeze is not obtained on second attempt, displace to 100' above holes. g. After squeeze is obtained, pull out of cement retainer and reverse circulate until returns stabilize. P.O.O.H. W.O.C. 10. R.I.H. with plug plucker and retrieve retainer. 11. R.I.H. with 6" bit and scraper. Drill out cement. P.O.O.H. ~~ 12. R.I.H. and retrieve bridge plug. P.O.O.H. and flow well overboard. 13. Rig up wireline and high pressure lubricator. Test lubricator to 3500 psi. Inject filtered injection water down casing a~ 3500 psi for 24 hours. Run R.A.T. injection profile survey. NOTE: If the HK/HN(U) is thiefing water (+1000 BDW) an extra isolation packer will be set at 10,164'. 14. Run tubing and packers as per attached sketch. Mark bottom packer with a radioactive tag. Position tubing in approximate location. Run gamma ray log and position packers. Space out to allow for 3~" slack off. 15. Drop ball. Pressure up to 1000 psi to set packer at 1D,O00'. Slack off 6". Increase pressure to 1500 psi to set packer at 9780'. Slack off 6'!. Pressure up to 2000 psi and set packer at 9600'. Slack off 6". Pressure up to 2500 psi to set packer at 9000'. Slack off 24'. Hold pressure and obtain tubin_c test. Increase pressure to 3500 psi and shear out sub. 16. Tighten lock down-screws. Install BPV. Nipple down B.O.P., nipple up tree. Test tree to 5000 psi. 17. Rig up wireline. Pull gas lift valve at 8960'. Fill annulus with 225 bbls. fresh water treated with Nalco inhibitor. ReKun dummy valve. Rig down wireline. · 18. Place well on injection into lower zones at 3500 psi. Approved TSB:KLE Date 9 10 11 12 I tern No. le 2. 3. 4. 5. 6. 7. 8. 9. 10. 11. 12. 13. Casing: 7", N-80, Tubing: 3-1/2", Perforations: GN/GO GR/GS HC/HD HE/HF HI/HK HK/HN HN/HR HR/HZ 23// 26// 99// 9.2~/, A33-14 Recompletion Detail Description X Nipple KBUG Unipacker VII KBUG Unipacker VII KBUG Unipacker VII KBUG Unipacker VII X Nipple Shear Out Sub Fish PBTD Depth. 300' 8,960' 9,000' 9,300' 9,600' 9,650' 9,780' 9,800 ' -10,000' 10,040' 10,050' 10,460' 10,487' from 0-6,500'_+ from 6,500'-9,900'+_ from 9,900 ' -TD N-80, EUE 8rd 9,061'-9,083'' 9,435'-9,451' 9,454'-9,472' 9,715'-9,804' 9,860'-9,888' ,954'- 5' 1 ,008'-~ 10,173'-10,239' 10,261'-10,302' 10,320'-10,460' le 2. 3. 4. 5. 6. 7. 8. 9. 10. 11. 12. _ A33-14 Workover Cost Estimate Operation Nipple Down - Nipple Up Cut and Pull Tubing Trip and Caliper Log Retrievable Packer Casing Tests Squeeze and W.O.C. Trip to Retrieve Retainer Drill CMT Retrieve Bridge Plug and Fish Packers Trip to Clean to Bottom R.A.T. Survey Run Tubing and Space Out Nipple Down and Nipple Up Rig Days 1 2 1 1 2 1 1 4 1 1 2 1 18 Rig Time @ $22,000/day Packers and Completion Equipment Rental Tools R.A.T., GR Correlation, and Caliper Logs Cementing Tubing Miscellaneous $395,000 35,000 30,000 30,00O 20,000 90,000 60,000 $660,000 Shell's 1/3 Share $220,000 Well History A33-14 Middle Ground Shoal Field November 1967 December 1967 October 1968 February 1969 March 1969 April 1969 May 1971 March 1972 May 1973 June 1973 December 1976 June 1978 July 1978 September 1980 November 1982 September 5, 1983 September 7, 1983 September 15, 1983 November 13, 1983 November 21, 1983 Spudded Completed. Initial rate: 2334 3DO, 5% cut Static temp. survey, pressure buildup and packer fl owmeter Convert to injection Static temp. survey and pressure fall-off survey and injection packer meter survey R.A.T. Survey R.A.T. Survey Pull well. Install isolation pa-kers. Pressure fall-off survey R.A.T. Survey R.A.T. survey Acidize with snubbing unit R.A.T. survey R.A.T. survey Acidize with coiled tubing Tubular and casing failure Run spinning survey. Indicated water leaving tubing below tubing han_~er. Well shut in Run temp. survey. Indicated possible hole in casing at 6300' MD. Rerun temp. survey. Again indicated holes at 6300' MD. Attempts to secure well by setting "X" plug in nipple at 898.0' failed. Nipple apparently corroded or scaled. A31-14 560 Gross 430 0il A32-14 440 Gross A33-14 1 go0 BDW (currently shut in) A44-11 ~ 11 O0 BDW Locat{on Plat HC Marker Middle Ground Shoal Field A11-13 Rd2 480 BDW A42-14 560 Gross 320 Oi 1 A34-14 Rd2 633 BDW C44-14 Rd 160 Gross 94 Oi 1 1000' .¢ -- · ., 3 4 ' . 6. · ? 9 10 11 12 13 14 ·. · · · , · ~OMPLETI ON DETAIL DESCRIPTION Safety Ball Valve Nipple Otis Type XO Sliding Sleeve Otis Type X Landing Nipple Gutberson RH~i Packer Camco KBM Mandrel w/ Dummy Otis Type XO Sliding Sleeve Gulberson R H-1 Packer Camco KBM Mandrel w/ Dummy Otis Type XO Sliding Sleeve 'Guiberson RM-1 Packer Camco KBM Mandrel w/ Dummy Otis Type XO Sliding Sleeve Guiberson RH-1 Packer Otis Type X Landing Nipple· · .e ~ · · % · Tubing Size J- 3~-" 9 3 ~/ft N-Sb & J-55 EUE · · · · · · · · · · · · GN 9,061'.. · ' , GS 9,472' o /~.,~- ymca. ~ /s~o · · 'Casing is N-80 Buttress with weights of: · · HC 9,715' 23#/ft from 0-6,500'~' HD 9,804''/2c~' · 26#/ft from 6,500'-9,900'+ 29#/ft from 9,900'- ID ' ' I~E 9,860' ~'oo · HK 10,008' O HN 10,162' · · Page 66 DEPTll + 296,C~ 8,946 8,980' 8,983' · 9,788' 9,825' · '9,828' 9,957' 9,993' 9,997' 10,124' 10,160' 10,164'' 10,170' JK i(L STATE OF ALASKA r.J[ ALASKAO AND GAS CONSERVATION CO ..,ISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL OTHER [] 2 Name of Operator 7 Permit No Shell Oil Company 67-68 3 Address Wayne Simpson, 601 West 5th St., t/810, Anchorage, AK 99501 4 Location of Well Conductor 30, Leg 4 @ 65.88' S & 49.28' E from Leg I @ 1627' N & 435' W from SE Corner Sec. 11, T8N, R13W, S.M. 5 Elevation in feet (indicate KB, DF, etc.) 116' DF 12 Lease Designation and Serial No ADL 18756 8 APl Number 50- 733-20051 9. Unit or Lease Name HGS 10 Well Numbe~ A 33-14 11. Field and Pool Hiddle Ground Shoal Check Appropriate Box To Indicate Nature of Not~ce, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Tr~phcate) (Submit In Duplicate) Perforate [] Alter Casing [] Perforations [-] Altering Cas,ng Sttmulate [] Abandon [] Stimulation [] Abandonment Repair Well [] Change Plans [] Repairs Made [] O.-her Pull Tubing [] Other [] Pulling Tubing [-I (Note Report multiple completions on Form 10-407 w~th a submitted Form 10-407 for each completion.) 13 Describe Proposed or Completed Operations (Clearly state all pertinent detads and give pertinent dates, including e~imated date of starting any proposed work, for Abandonment see 20 AAC 25 105-170) Job Cancelled. J ECEIVED JAN 1 1984 A/aska Oil & Gas Cons. C°mrni$$1orl ' Anchorage 14 I hereby c~[tlfy that tJ~e foregoing is true and correct to the best of my knowledge Prod. ^dm. S,gned Title ..~r. The space below for Commission use Daze 1/4/84 Conditions of Approval, If any By Order of Approved by. COMMISSIONER the Commlss,on Darte Form 10-403 Rev 7-1 Submit "Intentions" in Tr~phcate and "SubseQuent Reports" ~n Dupl,cate AS STATE OF ALASKA ~ ALASK IL AND GAS CONSERVATION C MMISSION SUNDRY NOTICES AND REPORTS ON WELLS I DRILLING WELL [] COMPLETED WELL OTHER [] 2 Name of Operator 7 Permit No Shell 0il Company 67-68 3 Address Wayne Simpson, 601 West 5th St., #810, ^nchorage, AK 99501 4 Location of Well Conductor 30, Leg 4 @ 65.88' S & 49.28' E from Leg 1 @ 1627' N & 435' W from SE Corner Sec. 11, T8N, R13W, S.M. 5 Elevation ~n feet (~ndmate KB, DF, etc ) 116' DF 6 Lease Designation and Serial No ADL 18756 8 APl Number 50- 733-20057 9 Unit or Lease Name MGS 10 Well Number A 33-14 11 F~eld and Pool Hiddle Ground Shoal 12 Check Appropriate Box To Indmate Nature of Not~ce, Report, or Other Data NOTICE OF INTENTION TO SUBSEQUENT REPORT OF (Submit ~n Tr~phcate) (Submit m Duplicate) Perforate [] Alter Casing [] Perforations [] Altering Casing Stimulate [] Abandon [] Stimulation [] Abandonment Repair Well [] Change Plans [] Repairs Made [] Other Pull Tubing [] Other [] Pulhng Tubing [] (Note Report multiple completions on Form 10-407 w~th a submitted Form 10-407 for each completion ) 13 Describe Proposed or Completed Operations (Clearly state all pertinent detads and g~ve pertinent dates, ~nclud~ng estimated date of starting any proposed work, for Abandonment see 20 AAC 25 105-170) Job Cancelled. 14 I hereby cg.r, tlfy that tJ~e foregoing ~s true and correct to the best of my knowledge $,gned T,tle Mgr. Prod. ^dm. The space below for Commission use Date 1/4/84 Conditions of Approval, ~f any By Order of Approved by COMMISSIONER the Commission Date Form 10-403 Rev 7-1-80 Submit "Intentions" ~n Triplicate and "Subsequent Reports" ~n Duplicate AC STATE OF ALASKA O~M ALASK IL AND GAS CONSERVATION C MISSION SUNDRY NOTICES AND REPORTS ON WELLS DRILLING WELL [] COMPLETED WELL I~X Injector OTHER [] 2 Name of Operator Shell Oil Company 3 Address John Douglas, P.O. Box 4500, Kenai, AK 99611 4 Location of Well Conductor 30, Leg 4 @ 65.88' S & 49.28' E from Leg I @ 1627' N & 435" W from SE Corner Sec. 11, T8N, R13W, S.M. 5. Elevat,on ~n feet (ind~cate KB, DF, etc.) 116' D.F. 12 6 Lease Designation and Serml No ADL 18756 7 Permit No 67-68 8 APl Number 50- 733-20057 9 Umt or Lease Name PIGS 10 Well Number A 33-14 11 F~eld and Pool Middle Ground Shoal Check Appropriate Box To Indicate Nature of Not~ce, Report, or Other Data NOTICE OF INTENTION TO' SUBSEQUENT REPORT OF' (Submit m Tnphcate) (Submit m Duplmate) Perforate [] Alter Casing [] Perforations [] Altering Casing [] Stimulate [] Abandon [] Stimulation [] Abandonment [] Repair Well [] Change Plans [] Repairs Made [] Other [] Pull Tubing [] Other [] Pulhng Tubing [] (Note Report multiple completions on Form 10-407 w~th a submitted Form 10-407 for each completion ) 13 Describe Proposed or Completed Operations (Clearly state all pertinent detads and g~ve pertinent dates, ~ncludmg estimated date of starting any proposed work, for Abandonment see 20 AAC 25 105-170) See Attached ECEIVED Gas C,~ns C'ommiS3io~ Anchorage 14 i hereby certify that thy foregmng ~s true and correct to the best of my knowledge /1 .~ ~/ ~/_ Signed .~(~ ~ Title Mgr; Prnd__ Admn The space below for Commission use Date 1~!4!P,3 Cond~uons of Approval, ~f any ORIGINAl. SIGNED BY LDI~IE C. SilTll Approved by. COMMISSIONER Approved Copy Returned By Order of the Commtss~on Date /(~/~ /~ Form 10-403 Rev 7-1-80 Submit "Intentions" ~n Triplicate and "Subsequent Reports" ~n Duplicate ~ AU~I'%~)RITY FOR EXPENDITUI~ ( PRODU~ION PACl FIC DIVISION HOU~ON ~~ OF ~~ ~IA~ A33-14 M~dd]e Ground Shoal ~e]d 9/22/83 Cook Inlet, Alaska ORDER ~.E DE~RI~ION , , NUMBER 1~ CO~ aU~ N~-.~ E~ ~AL R&R Determine loc~on of ~ub~ng $15,00~ $5,000 $5,000 and c~s~ng leaks ~n A33-14 Non Ope~e~o~s Approve1 Requ~ ~ed Requested b~' ~. H. Dougles T. S. Burns ' su.--TOT~ $15,00( $5,000 $5,000 BUDG~ AVAILABLE IN BUDGET RETIREMENT POSITION NEW CAPITAC FUNOS REQUIRED BY BUDGET REVISION TOTAL COST ~ ~5 s000 JUSTI F ICATI ON: - _ _ See ~ched ~us~fic~on. . . OCT i . Alaska Oil & Gas Cons~ Ar]chorage CONTINUiO '" , RECOMMENDED APPROVALS Justification Tubular Leak Detection A33-14 Middle Ground Shoal Field Funds totalling $15,000 ($5,000 Shell's 1/3 share) are requested to locate the tubing and casing leaks in well A33-14, Platform "A", Middle Ground Shoal Field, Cook Inlet, Alaska. Well A33-14 was drilled and completed in December 1967. The well was converted to an injector in February 1969 with an initial injection rate of 6000 BDW. The injection rate declined to a rate of 1900 BDW by August 1983. On September 5 1983, well A33-14 started takinq more than_4~O00 BDW a~ ~i. A s~inner survey conducted indicated ~'h~-wate~ w~S~-~a~ng the tubing at a shallow point. The survey also indicated that water may be crossflowing up from the Hemlock Zone into a shallow zone where the casing holes (?) exist. A temperature survey run indicates that a probable casing leak exists between 5072' and 5484'. A R.A.T. injection survey will confirm the location of the casing leak and possibly locate other leaks. R&R action will be planned accordingly. Conducting this job will save at least 1/2 rig days in locating the casing leaks which would pay out the cost of the survey. Prognosis Tubular Leak Detection A33-14 Status: Well Shut in. Probable tubing and casing leaks. Objective: Determine location of tubing and casing leaks. Procedure: le Rig up wireline and lubricator. Test lubricator to 3500 psi. Make drift run to bottom. Record on log heading. Rig down wireline. 2o Maintain constant injection rate of 3500 psi pressure for 3 days prior to and during the survey. Record on log heading. o Rig up service company's lubricator (high pressure - wireline), stuffing box, collar locator, continuous flow meter, and radioactive tracer with ejector and two radioactive detectors. 0 Tie into depths with collar locator in casing. Log tubing to surface with CFM to determine tubing leaks and/or fluid leaving tubing and re-entering at a lower location. If casing leaks are suspected, confirm and locate using R.A.T. 0 Shut well in at surface. Determine rate at which crossflow (if any) occurs. 6. Rig down service company, shut well in. TSB: mh Approve~ ~ Date \Cb ~ j , 10 13 o~O r i)t£ S O,R i PT ~ ON Safety Ball Valve Otis Type XO SlSd~ng Slcave Otis Type X Londlng Cuiberson RII~I Pac,,~'r Camco KE, H Handrel w/ Otis Type XO Slidiug S]eeve Guiberson RH-1 Packer Camco KL~ Handrel w/ Dt~nmy OPis Type XO Sliding Sleeve Guiberson RI{-1 Packer Camco ~M Handrpl w/ Dum~my Otis Type X0 Sliding Sleeve Guiberson RH-1 Packer Otis Type X Lsnding Nipple. ~ ..' , , z96 aS0' 8,~83' 9,788' 9,825' 9,628' 9,95/' 9,D93' 9,597' 10,]24' 10,160' 10,]64' 10,170' Junk @ 10,460' PBTD = 10,487' 9,061' 9,472' c> 9,715' =ItP 9,804' /2 c~ · , Tubing S'ize-- 3½", 9.3 f//ft, N-Sb & J-55, ElSE . /,,/," : HE 9,860 IlK4/t9,995 : HK 10,008' O [ HN 10,162' Casing is N-80 Buttress with weights of: · .. , 23#/ft from 0-6,500'~ 26#/ft from 6,500'-9,900'~ 29#/ft from 9,900'- TD ' ff l- /-~ /¢ · ' lin 10,173' 10,460~. · 7" Casing @ 10,531' . Page 66 1K \ POS 11449 ~,Y '+~ ~ . ~ INJECTION WELL 1~ , t o PRODUCING WEL~ I DRILLING WELL [] 2 Name of Ope-ator SHELL 0TL COMPAHY COMPLETED WELL Injector 99501 3 Aodrass ATTN' !'!ayne Simpson 601 W. 5th Ave., #81___0_, Anchoraqe, AK 4 Lccat~on of Well Conductor 30, Leg 4 @ 65.88' S & 49.28' E. from Leg 1 @ 1627'N to 435'W from SE Corner Sec. 11, T8N, R13W, S.M. Lease Designation and Serial No ADL 18756 5 Elevat~on m feet (indicate KB, DF, etc.) 116' D.F. 7 Permit No 8 APl Number 50-733-20057 9 Unit or Lease Name MGS 10 Well Number A 33-14 11 F~eld and Pool MIDDI_E GROIJND SHOAL "G" POOL OTHER 12. Check Appropriate Box To Indicate Nature of Not~ce, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Ferfo~ate L_~ Alter Casing [] ~ Perforations [] Altering Casing [] St,ch ';late [] Abandon r-j Stimulation [X'] Abandonment [] Pepa r Well ~ Change Plans [] Repairs Made [] Other [] Pull T,,b~ng [-] Other [] Pulling Tubing [] (N~te Ft,,zport,nufth)lecdmolet~oqs on Form 10-407 w~th a subm,tted Form 10-40~ for each comolet,on) -~5 D~;;u,~be-Pr~op~s~ o;-~rrpfete,~-~;~-t,~-TC~Sy-s~,;~e all pertinent oetads and give pertinent dates, including estimated date of p~op,ps~d worK, ~or ~b~nden,,~nt see ~0 A~C 25 ~C5-1 Jl/tg/82 Rig{led up a~ic coiled tubing and DoN,'ell. ?rcssure tested to I 5000 PSIG from pu~qping unit to swab gate. ]'esLed BOP. 11/20/82 R. I.H. i0400' Pumped 10404' HCL-HF tubing and tagged bottom @ 10404'. Washed perfs from 10170'- with 7% ttCL. Pulled up to 10000' to allow acid to soak. 495 gals !2%-10% ltCLq'.F acid across perfs from 10170'- · Pulled up to !0000' to allow acid to soak Repeated the process· Pumped 15 BBLS H20 @ 4000 Dsi to ~isplace coil · Reran coil tubing to 10404' and repeated 12%-10% process. Pu~,~ped 15 BBLS H20 to displace coil tubing. Soaked 30 min. Ran tubing to 10404'T Pumped 495 gals 12% HCL while moving coil tubing up hole to 10170', displaced with 100 BBLS H20. Pulled tubing out of hole. Displaced H20 in coil tubing with 15 BBLS diesel. Rigged down and moved e~'uipl,~ent.~-~ ~ RECEIVED DEC 0 1982 Alaska Oil & Gas Cons. C,¢l'nmlsol:' o' Anchorage 14 I he;eby ce~t,~y that the foregoing ~s t-ue and correct to the best of my knowledge s,.~,~od . T,t~e PRODUCTION ADHINISTRATION The soace bei,.~,~ for Commission use __ C~,~dlt oq.~ ct Approval, if any ~M~', Da,e 11/29/82 By © der of &g,p~cv~c bv .... COr,IMISS,ONER the Corem,ss,on Fo, m 10403 Rev 7 I -80 Date Submit "Ir'teqtl:D~s" itl Tr,pt~cate and ?u~,equ=,'~! Pepc[ts ' ~n Dupt'cate STATE OF ALASKA ALASKA (~ AND GAS CONSERVATION CG~ MISSION SUNDRY NOTICES AND REPORTS ON WELLS 1 DRILLING WELL [] COMPLETED WELL)~ OTHER [] 2 Name of Operator SHELL 0IL COMPANY 3 Address Uayne Simpson 601 W. 5th Ave... #810, Anchorage, AK 99501 4 Location of Well Conductor 30, Leg 4 @ 65.88' S & 49.28' 'E from Leg I @ 1627'N to 435' W from SE Corner Sec. 11, T8N, R13W, S.M. 12. Lease DeslgqatJon and Serial No. ADL 18756 7. Permit No. 8. APl NJmber 5c- 133-20057 9. Unit or Lease Name HGS 10. Well Number A 33-14 11. Field and Pool HIDDLE GROUND SHOAL "G" Pool Check Appropriate Box To Indicate Nature of Not~ce, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit m Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] ~ Perforations [] Altering Casing [] St,mulate X~ Abandon [] Stimulation r-] Abandonment [] Repair Well [] Change Plans ['l Repasrs Made [] Other [] Pull Tubing [] Other [] Pulhng Tubing l-] (Note Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Descr,be Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25 105-170) SEE ATTACHED RECEIVED NOV 0 a 1982 Alaska 0il & Sas C~no. ~,,~,,;,. Anshoraga 14 I hereby certify that the foregoing ss true and correct to the best of my knowledge S,gned /~ ~~'~ T,tle PRODUCTION ADMINISTRATION The space below for Commission use Date 10/21/82 Cond,t~ons of Approval, if any. Approved by BY ~'.'~,SB, Y ~]. E[IGLEE COMMISSIONER Approved Copy Returned the Commission Form 10~,03 Rev 7-1-80 Subm,t "Intentions" ~n Tr~phcate and "Subsequent Reports" in Duohcate Stimulation Prognosis A33-14 Status: Currently injecting 2100 BDW into the HK/HN, HN/HR and zones. Objective: Procedure: Increase injection by stimulating the HN/HR and HR/HZ zones with acid placed using coiled tubing. Note: (Shut off injection +48 hours before rigging up coiled tubing unit). 1. Rig up slick line, test lubricator to 3500 psi. Make a 2" drift run to bottom +10487' (fill at +10431'). Tag and record depth. Place dummy valves in all open mandrels. Place well back on injection to test rate out the bottom of the tubing. 2. M.I.R.U. coiled tubing unit and Dowell acidizing equipment. Test tree and coiled tubing unit to 5000 psi. Test hydraulic system and BOP. 3. Run tubing in hole slowly (no more than 100 fpm). Circulate while running in hole using filtered inlet water with 3500 psi pressure of CTU and ±1500 psi back pressure on tubing annulus. Tag bottom (10,487' PBTD). If fill is above bottom perforations at 10,460', notify T. S. Burns (713) 870-4465 or (713) 980-4373 (home). 4. Make three passes through perforations (10460'-10173') while circulating inlet water. 5. With coiled tubing at 10,460', spot 495 gal. of 7% HC1 with 0.3% W-35 (anti-sludge), 0.2% F-75N (surfactant) and 1.0% A-200 (inhibitor). Slowly move coiled tubing uphole while spotting acid in order to cover all perforations (10,460'-10,173'). 6. P.O.O.H. with tubing to 10,000. Wait 30 minutes after clearing tubing and pump 12 bbls of injection water. 7. Run coiled tubing to ~/~,460', spot 495 gal. of 12%-10% HC1-HF acid with 1.2% A-200. Slowly move coiled tubing uphole while spotting acid in order to cover all perforations (10,460'-10,173') with acid. Pump 19 bbls of injection water to clear coiled tubing. i~. P.O.O.H. with coiled tubing to 10,000', wait 30 minutes after clearing tubing of acid and pump 12 bbls of injection water to ~0~0 ~ ~B~ displace spent acid. .... ~;'~L](~peat Steps 7 & 8 two times) 9. After repeating Steps 7 & 8 two times, pump 495 gal. of 7% HCl with 0.3% W-35, 0.2% F-75N and 1.0% A-200. Move coiled tubing from 10,460' to 10,173' while pumping. Clear tubing with 19 bbls of injection water. P.O.O.H. to 10,000. Wait 30 minutes and pump 20 bbls of injection water to displace acid into perfs. 10. Pump 100 bbls injection water while moving coiled tubing up and down through treated interval. 11. P.O.O.H. and rig down. Put well on strip chart, return well to injection at 3500 psi and test. Report rates to T. S. Burns in Houston. Note: While working on water injectors, do not leave tubing standing in well without fluid movement. Blow coiled tubing dry with rig air after rigging down. If rig air is not available, cover coiled tubing reel and keep heated or circulate 50% methanol and 50% inlet water. Approval Date Coiled Tubing Stimulation Cost Estimate A33-14 1. 990 gal. HC1 3 gal. W-35 2 gal. F-75N 10 gal. A-200 2. 1485 gal. HC1-HF 18 gal. A-200 3. Pump 1.5 days 4. Tanks 1.5 days 5. Lines 6. Personnel 1.5 days 7. Miscellaneous 8. Coiled Tubing Unit 1.5 days @$1.10/gal. @$ 33/gal. @$ 36/gal. @ 34/gal. @$ 2.4/gal. @$ 34/gal. @$1,300/day @$ 470/day @$ 924/day @$15,000/day Transportation Total Say $ 1,089 $ 99 $ 72 $ 340 $ 3,564 $ 612 $ 1,950 $ 705 $ 2,000 $ 1,386 $1,ooo $22,500 $ 1,100 $36,417 $37,000 ITEM NO. · 1 3 4 · 5 6 7 8 9 10 11 12 13 14 MGS WELL A 33- 14 COMPLETION DETAIL DESCRIPTION Safety Ball Valve Nipple Otis Type XO Sliding Sleeve Otis Type X Landing Nipple Guiberson RH-1 Packer Camco KB}f Mandrel w/ Dummy Otis Type XO Sliding Sleeve Guiberson RH-1 Packer Camco KBM Mandrel w/ Dummy Otis Type XO Sliding Sleeve Guiberson RH-1 Packer Camco KBM Mandrel w/ Dummy Otis Type XO Sliding Sleeve Guiberson RH-1 Packer O~is Type X Landing Nipple · · 296' 8,946' 8,980' 8,983' 9,788' 9,825' 9,828' 9,957' 9,993' 9,997' 10,124' 10,160' 10,164 ' 10,170 ' Tubing Size-- 3½-" 9 3 #/ft N-ab & J-55, EUE GN - GS HD 9,061' 9,472' ~ 9,715' 9,804' /?ce 5 HE 9,860' HK 10,008 ' -[ HN 10,162' ~ HN 10,173' /7~ ~/~,i~l ~' HZ 10,460' . Junk @ 10,460' O Casing is N-80 Buttress with weighta of: 23#/ft from 0-6,500', 26#/ft from 6,500'-9,900'+ 29#/ft from 9,900'- TD ' PBTD = 10,487' ~ 7" Casing @ 10,531' Page 66 JK WESTERN E&P OPE ,~ON$ [~igDLE"Gf~0UI~!B Sfi0gL FIELD SHELL-ATLANTIC-STANDARD PATTERN '"~.1' [/ . _ .... I / /i~ ~ -"-0'/' ,il · ~ . _+ _~_--~ _ · ~ , ~' ~ / :¢ ' . ~ I I ,¢3 / ~, / I' ADL 1175J I INJECTION WELL PRODUCING WELL ~P.A. PLUGGED & ABNB -- · ! ! jO4000 Telephone (907) I 1/4" COILED TUBING SPECIFICATIONS Actual O.D. Nominal I.D. Wall thickness , Weight Wall area Flow area Tensile: Ultimate Yield Max. Operating 1.250 in. ~. 084 in. O. 083 in. 1. 034 lbs/ft. 0.304 in.2 0.925 in. 2 22,800 lbs. 300 lbs. 000 lbs. Burs t: Ultimate Test press. Max. Operating 9,960 psi. 6,000 psi. 5,000 psi. Collapse: Ultimate Max. Operating Capacity: Wall displacement Total displacement 6,100 psi. 1,500 psi. 1.141 Bbl/1,000 ft. 875 ft./Bbl. 0.377 Bbl/1000 ft. ( ( SCHLUMBERGER O. FFSHORE SERVICES A D,v,s~on of Schlumberger L,m~ted HOUSTON, TEXAS 77001 October 20, 1980 .Shell Oil Company - Alaska Operations 601 W. 5th Avenue - Suite 810 Anchoraqe, Alaska 99501 Attenhon' Production S_uperintendent PLEASE REPLY TO ~;CHLUMi~ERGER OIrFSHORE SERVICES 500 W International Airport Road Anchorage, Alaska 99502 Gentlemen: Enclosed are 1 ._Blbrints of the I ' CompanyShell Oil Compan_y .'I F~eid Middle Ground Shoal Addihonal prints ore be,nc sent to' 1 BLprints Shelq 0il Company North Star Route 1 Box 485 Kenai, Alaska 99611 Engineered_ Pr_od_u_ction LQg$ (2) ..... ~ ........ ~_z~,~ on. ' Well_ MG_S__C3_2-2_3__(9~33-14 (g/~ , County Kenai 1 RFolded Sepia ] BI_ pr,nts Atlantic Richfield Company P.0. Box 360 Anchorage, Alaska 99510 Attention' J.W. Hart 1 BkDrints .... She1'1 0il Company .... P.0. Box. 831 / Pacific Division Houston, Texas 77001 AttentiOn' E-~I Scott 1 BL prints Amoco Production Company P.O. Box 779 Anchorage_, A_las_k_a_ ..... _99510 Attention' L.A. Darsow 1 B/ri t.~ She~ ~1 Company Western E & P'"R6-glon P.O. Box 576 Houston, Texas 77001 Attention' E & P Files 1 RRolled Sepia 1 BLprints Chevron U.S.A., Inc P.O. Box 7-839 Anchorage, Alaska 99510 Attention' C.F. KirkVold 1 RFo~sSepia State of Alaska _D_iy_i_sj~_n of_ Oil & Gas Conservation 3001 Porcupine Drive Anchoraqe, Alaska 99510 prints I-is Returned to Shell The f,i~estern EI I~p --IH(~Uston) f loSaSe return one copy of this letter our files- Thanks, We appreciate the privilege of serving you. Company- Very truly yours. SCHLUMBFRGER OFFSHORE SERVICES DISTRICT MANAGER Re}eas~ Date Sec. ;- ~,~ .¥:[. Operator Shell Oil Co. Lease No, A .... o75o or Owner 2,_'ic!d].e Ground Shoal We! t No, A-33-14 Area ~,_ Perm i t No. ,~ - c,,,., Issued iv ~-,'' ~ '~ Conductor 30, ~c~.',"' -4 Location (Surface) 1.5~! Z.'SL &~oo"'~'~* ~.~.~>-~r- Sec, ~" Loc, (Bottom) i753~ ?S* &.29~4' v .... ~'~ 14 INDIVIDUAL WELL RECORD Spud Date 11-2-67 D,rilling Ceased Total Depth i0,555' Suspended Aban don cd Completed (F-Cfi/TP/)/___].2_~~__67 ~_:if 2177 Elevation 36~4° O.5 B/D, Grav APl Cut ].16 DF Gas 830 MCF/D, Bean 12g /64 CPo.~n psi, TP 90 psi SxCmt Peri': 9A56'-72' ;97!5 ~-~04' ;9~60' ,.. ' .... ''°~'L'-°5' O~O__,Q ' '~ ' i0,173~-239~'~ zo= 26i~-302'; t~C3 ~0,3~'-/, ' _P]_ugs 3939 GEOLOGi C FORMA?IONS Surface Lowest Yes ted PRODUCTIVE HORIZONS Name Depth Con ten ts WELL STATUS Year Jan Fab Mar Apr Hay June Jul,/ ...A_u_u 9~ Sept Oct f,'~v D,xc SHELL OIL COMPANY 430 71'1-1 AVENUE ANCHORAGE, ALASKA 99501 February 19, 1969 HLB TRM ~ OKG - ~'~"~'~ KLV jJ ' - HWI( .... ~, _ FILE State of Alaska Oil and Gas Conservation Committee 3001 Porcupine Drive Anchorage, Alaska 99501 Attention Mr. T. R. Marshall, Jr. Executive Secretary Gentlemen: Pursuant to State of Alaska Oil and Gas Conservation Regulation 2228 - Notice of Operations we hereby no__that injection oper- ations were commenced in we~ls A-12-12 an~.~{on February 18, 1969. Injection fluid was treated Cook Inlet water. Both wells are undergoing injection rate-pressure tests and stabilized rates have not been estab- lished. Injection does appear to be satisfactory, however. Very truly yours, A. A. Winn Division Production Manager cc: Standard Oil Company of California Atlantic Richfield Company Pan American Petroleum Corporation ALASKA OIL AND GAS CONSERVATION COMM I TTE E December 31, 1968 Re: PRESSUREt)MAI NTENANCE MIDDLE GROUND SHOAL FI ELD Administrative Approval For Conversion of Three Middle Ground Shoal Wells From Producing to Injection Status Mr. A. A. W inn Division Production Manager Shell Oil Company 430 Seventh Avenue Anchorage, Alaska 99501 Dear Mr. Winn Your application dated December 20, 1968, requesting administrative approval of the conversion of the Middle Ground Shoal A-12-12, A-33-14, and A-11-13 we~tls (Shell O~1 Company, operator) from producing to injection status is hereby approved. Very truly yours Thomas R. Marshal 1, Jr. Executive Secretary TRM:may Vezy truly R. D. ALLEN Division E::ploi J, Clotdt A~lantic Richfield Oil C~mpany~ Attn $,1.I, Ktngsbury Pan U.S.G.S., A~tn ~'J- L~aton ~'lcKeever Area Productic~. State of. Alaska, Division of · Enclosures bce: Standarf Oil ComPany of Calif., At~n RECEIVED FEB 14 196B DIVISION Of MINES a MINERAI~~ ANCHORAGE F ~r,~m No STAT E~'F ALASKA OIL AND GAS CONSERVATION CO/%MI]TEE OIL ~ G~.~ ~-~ SUB.~I~r L~ DEPLICA~ 2 N ~,IE OF OPF2~.I Ok Shell Oil Compf_n_l 3 ADDt-IES~ O~ 430 Seventh Avanue: Anchorag_e_~_Alas a~99501 4 LOCi i ION OF %% EL Conductor 30, Leg 4 @ 65.88'S & 49~28'E from Leg 1 @ 1627'N & 435'W from SE corner, Section 11, TSN, R13W: S~M. ~~kc.~ 50-133-20057 S LI, ASE Di-$ O', ~ -,C\ -',.', D >E {,AL NO ADL 187 56 7 I1: INDIAN None Middle Ground Shoal 9 %% ELL .NO A-33-14 i0 ~iEL.D .%TD PC~OL 0.' I%iLDC¥!_ Middle Ground Shoal 11 SEC 1 R Al ,BO2ZfO'I ¼OL.E OBJ-IECTIVE, Sec. 14, TSN, R13W~ SoMo 12 PiTkM IT 67-68 13 RE. PORT 'IOTAL D1CPT'H AT EN'D OF MOXFFt CH~N-GES IN }IOLE SI~F CASING ~N~ C~IEN~iN(~ JOBS INCLUD'NG DEr'Itt SET ~N'D VOLL~S USED PERFOR~qlONS ~SiS AND ~FSCLTb FiSHtXG JOBS JL~K tN' HOLE kN'D SIDF-T}TACKED zlOkE ~N~ ~N'Y OT~R SIGNIFICANT CHANGt%S IN HOL~ CONDITIONS Cemented 7" casing at 10,531' with 1100 sacks. Ran in with bit and scraper on 3-1/2" tubing. Lost bit at 6596'. Pushed bit to 10:427'o Ran Legs, Worked bit to 10,484'. Ran 3-1/2" tubing to 9003'~ Set packer at 8939'° Perforated through tubing with 4 jets/ft~ 9061-9083' 9715-9804', 9860-9888'~ 9954-9995'~ 10,008-10,162'~ 10~328-10,460'. Placed well on gas lifto Released rig 2:00 a.m. 12-7-67. 9435- 9451 ' 9456- 9472 ' 10~173-10,239' 10 261-10 302' ~~~4d~X~y/ nTt a Div. Exp 1 o it a tio n E n g inee ~.~, /- ~- ~ ~' NOTE--Report on th~s form IS required for each calenda- month, regardless of the status of operations, aha must be f:~eO in duphcatt w~th the D,ws~on of M,nes & Minerals by the 15th o[ the succeeding month, unless othe~se d~rected SHELL OIL COMPANY 430 7TH AVENUE ANCHORAGE, ALASKA 9950I January 4, 1968 Confidential Material STATE OF ALASKA 3001 Porcupine Drive Anchorage, Alaska Attention T.R. Marshall, Jr. Gent lemen: Enclosed are the Monthly Report of Operations (2 copies each) for December, 1967, for our Middle Ground Shoal wells, A-14-1, A-33-14, C-23-26 and C-31-26. R.D. A1 len Division Exploitation Engineer Enclosures Form No P---4 STATE OF ALASKA su~ O~L AND GAS CONSERVATION COMMITTEE MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS WELL WELL 2 NA/vIE OF OPKgATOR Shell Oil Company 3 ADDRESS OF OPER&TOR OTHER 430 Seventh Avenue~ Anchorage, Alaska 99501 4 LOCATION OF WELJ. Conductor 30, Leg 4 @ 65o88'S & 49.28'E from Leg 1 @ 1627'N & 435'W from SE corner, Section 11, T8N, R13W, SoM. ApI NL~iE~CAL CODE 50-133-20057 LEASE DESIGNATION AND SE1RIAL NO ADL 18756 7 IF INDI CN, %LOT~E OR TRIBE NASIE None 8 L~'IT,FAi~%{ OR LEASE NA_RIE Middle Ground Shoal 9 %VELL A-33-14 10 F!F.I?) A.N'D POOL OR %VILDCAT Middle Ground Shoal 11 SEC, T, R, A{ ~BO~TO~{ HOLE OBJECTIVE) Sec. 14, T8N~ R13W; S.M. 19. PER-MIT NO 67-68 13 REPORT TOTAL DEPTH AT END OF MONTH, CI~A~NGES IN HOLE SI~E, CASING A-ND CEA~ENTING JOBS INCLUDING DEPTH SET AN]) VOLU1ViES USED, PERFORATIONS, TESTS AiN-D RESULTS FISHING JOBS, JI/~K IN HOLE A.ND SIDE-T1R~CKED HOLE AND A_NY O~HER SIGNIFICANT CI-L~N~ IN HOL~ CONDITIONS Cemented 7" casing at 10,531' with 1100 sacks. Ran in with bit and scraper on 3~1/2" tubing. Lost bit at 6596'. Pushed bit to 10,427'. Ran Logs. Worked bit to 10,484'. Ran 3-1/2" tubing to 9003'. Set packer at 8939'. Perforated through tubing with 4 jets/It, 9061-9083', 9435-9451' 9715-9804', 9860-9888', 9954-9995' 10~ 328-10,460' o Placed well on gas lift. Released rig 2:00 a.m. 12-7-67. , 9456-9472', , 10,008-10,162', 10,173-10,239', 10,261-10,302' RECEIVED JAN DIVISION OF MINES & MiNERA~ ANCHORAGE cer~ffv~e re in rrect 14 Ihe re by//~/~ m~N~D . ~r~Div. Exploitation Engineer~a~ NOTE--Report on th~s form ~s required for each calendar month, regardless of the status of operat,ons, anO must be filed m duphcate w~th the D~wsmn of Mmes & Mmerals by the 15th of the succeedmg month, unless othe~se d~rected (' Confideu t.i.~ 1 ?4ntcria i ST;.~ OF 3001 Porcupina Drive Anchprcge, A!,-ska ~,.~i.~. T ~. i-:arsha!l, Jr. Gent ! s{r.=n: Enclosed ara the Monthly R,port of Operation~ (2 copios each) for l~Te~l, er, 1967, for cur l.iiddle Ground Shoal walls, A-!2-!2, A-33-14 and C-31-26. ' Enclosures bcc: Very truly youro, Or-~-~ina! Sig~. ~-~d t{o D. R.D. Allen Division Exploitation Engineer Standard Oil Company of Calif.,'attn J. Cloidt Atlantic Richfield Oil Company, attn S.W. Kingsbury Pan ~?,erican Petroleum Corp., attn. J.H. McKeever U,S,G.S,, attn W.J. Linton Area Production State of Alaska, Division of Lands, attn Pedro Denton RECEIVE-D FEB 20 196 DIVISION OF MINES & MINERAI~ ,KNCHOP, AGE SHELL OIL 430 7th ANCHORAGE, COMPANY AVENUE ALASKA ~95OI JAN -. 4 1968 At~en{.~n T,5, Mar.~ha!l~ J~, Enclosures Standard Oil Company of Calif.; Attn J. Cloidt Atlantic Richfield Oil C~mpany~ Attn S.W. Kingsbury P~n American Petroleum Corp., Attn J.H. }~Keever U.S.G.S., Actn W.J. Lin~on Area P£oduc~ion State of Alaska~ Division Of Lands, Attn Pedro Denton STATE ( ALASKA OiL A'qD G/S CONS[F,'VATION 2 .',, :- C.- G- Shell Oil Cor,pany OTP Yj~ 430 Savc, nth Avenue, Anchorage, Alaska 99501 SUE~%IiI IN DKPIICA. TE '~ ...... AP1 50-133-20057 C=nc~cter 30, Lag 4, @ 65,88'S & 49.28'E from Leg 1 @ 1627'X & 435'W from SE corner, Section 11, T8N, R13W, S ADL 18756 A-33-14 MJdd!e Ground Shoal Sec. 14, TSN~ R!3i:, S.Mo 12 P~!%M I'i 67-68 13 P.~--~_,~.. TO'fAt T)Fi'_P'i-~r AT .END OF ~,'O'~.~' CKA. QZ~- ~'f }fC)L,P. S!~!7 C ~-qI.",'O A.-NW) CE'dEN'TI.NO JOTS l\C'LL iD.NC .T)if~-:-~ SFT .k."JD %LLU~'r~S USE'9 PI-zrO~.IAil().~> Tlgblb .,~%-D P~-~>LLTS FISt[lNG JOBS JU-~}'~ IN HOLE, A_\'D SiDE-i ~.JKED : ~_,-i A. ND ~>;'.- O-r'~E.:( S:~.~,IFICA'-'T CK;\NGE.% IN HOL~ COl'eDITIONS Spudded 4:30 a.m, 11-2-67. Drilled 15" hole to 1890'. Cemented 10-3/4" casing at 1871' with 1975 sacks. Drilled 9-7/8" hole to 10,555'o Ran logs. RECEIVED FEB 2 0 196 DIVISION OF MINES & MINERAL8 ANCHORAGE ',O'r~--~.F-~rt o: th,s form IS required for each caler, dar month, regardless of the status of ooerat~:-s, ar: r~-'st be f,led m * ', - ' the D,~'s,:- d ',',nes & Minerals by the 15th of the succeeding month, unless otherwise d~rected SHELL OIL COMPANY 430 7th AVENUE aNChoragE, aLasKa 99~01 December 28, 1967 CONFIDENTIAL MATERIAL STATE OF ALASKA Division of Mines & Minerals 3001 Porcupine Drive Anchorage, Alaska Attention: T.R. Marshall, Jr. Gentlemen: Attached are two copies of the Well Completion Report for our SAS Middle Ground Shoal A-33-14. Included with the report are the following data: Composite Log (Sepia & Print) Directional Survey (2) Well History (2) Very truly yours, Division Exploitation Engineer WH/jb Attachments RECEIVED D/VI,SiON OF MINE,S & Form P--7 [' SUBMIT IN DUPI. STATE OF ALASKA ',see other In- St ructions on ~)IL AND GAS CONSERVATION COMMITTEE I I I WELL cOMPLETION OR RECOMPLETION REPORT AND LOG* la. TYPE OF WELL: on,%VELL ~-~ (,ASwELL [-~ DRY ~-~ Other b. TYPE OF COMPLETION: NEW ~-~ WORK[] DEEP-[] PLU(, ~--] DIFF [] %VELL 0% ER E.% BACK EESVR Other NAME OF OPERATOR SHELL OIL COMPANY 3 ADDRESS OF OPERATOR 430 Seventh Avenue~ Anchorage, Alaska 99501 ~'. LOCATION Or WELL (Report location c]ear~t; and in accordance with any State requ,reraents)* At surfaqe Conductor 30, Leg 4 @ 65.88' S & 49.28' E from Leg 1 @ 1627' N & 435' W. from S.E. corner Sec. 11, T8N, R13W, S.M. at to~ ~ro4 l,t~rval ,,~ort,a below (9061') 3008' S & 1417' W from N.E. corner Sec. 14, T8N, R13W, S.M. At total depth (10,555') 3527' S & 1934' W from N.E. corner Sec. 14, T8N, 50-133-20057 6 LE~SE DESId~k~XON A.ND SEI~L~L NO ADL- 18756 IF INDIA21, ALLOTTEE OR TI~BE NAME NONE UNIT,FA~,IVI OR LEASE NAME MIDDL~ ~ROUND SHOAL WELL NO. A-33-14 10 Fr~r.r~ AND POOL, OR WILDCAT MIDDLE GROUND SHOAL 11. SEC , T , R , M , (BOTTOM HOLE OBJECTIVE) Sec. 14~ T8N, R13W S.M. 1~. PInch, fIT NO R13W, ,S .M. 67-68 11/2/67 ] 11/30/67 [ 12/7/67 ~ ~ ~ 116 DF ... , --- 18 TOTAL DEPTH, 1ViD & TVD~IB. PLUG, BekCK MD & TVD~/~; IF I%AXJLTIPLE COM~L, ! 21 ' INTERVALS "DRILLED BY ~ [ HOW 1VIJkNY* ~ ROTARY TOOLS CABLE TOOLS 10,555 CSS04) /10,487 (8743) I --- I 10,555 --- ~2. PRODUCING I1N"r~I~VAL(S), OF THIS COMPLETIO/q--TO~, BOTTOM, NAME (MD AND TVD)* 9061' E Pool 9061' (7506) 10,460' G Pool 10460' 24 TYPE ELECTRIC AND OTHER LOGS RUN DIL ; BHC ~ CBL CASING SIZE WEIGHT, LB/FT 7" 23 WAS DIRECTIONAL SURVEY 1VIAD E (8718) , j yes CASING RECOHI) (Rel~ort all ~trlngS set in well) DEPTH ~ET HOLE SIZE CEAILNTING i%ECORSD · 1975 sacks 100 sacks ., 26 LINER I~ECOi~D SIZE TOP (MD) BOTTOM (MD) l SACKS CE~VIE~T* 28 PERFORATIONS OPFA~ TO PRODUC41'IO~ ' (Inte~al, s~ze and number) Perforated 1/2" holes~ 4 jets/ft. 9061-9083' 9435-9451; 9456-9472~9715-9804~ 9860-9888; 9954-9995; 10~008-10~162; 10~1~3-10~f39; ' 10~261-10~302; 10~328-10~460. i I so PEODUCTION 27 TUBING RECOlq~D SCREEN (MI)) SIZE t DEPTH SET (MD) ~ PACKER SET (MI)) ~ , 3-1/2"~ I 9003' I 8939' 29 ACID, SHOT, F~-i~C"I'LrRE, CEaVIENT SQUC~E, CC D~I ~EV~ (MD) ~ ~O~T ~ ~ O,F ~E~ U~ A2VI OLrN'T PULLED nong none DATE FI1R.S~ PIiODUCTION ! PRODUCTION ME~iHOD (Flowing, gas lift, pumpmg--slze and type of p~p) [WELL STA~S (~oduc~ or [ ~nut-~n) ] ?./7/.67 t Flowing ~* ] Producing -- FLOW, EBING l~mG ~s~ [CAL~~ -OI~BBL GA~ W%~B~ ]OIL GRAVITY-~ '}C~ ) 90 ] 800 I ~ [ 2177 ~ ' I 830 I ~ ~ I 36.4° 31' ~XSP0StT~0S Or a~S (Sold. ~se~' f~r y~e~. ,e~te~. etc ) TEST WITNESSED BY Vented Well History, Directional Survey, Sepia & Print of Composite DIL. sIOSmm ~~~U~ ___ ~ TITLE Division Exploitation Eng. ~) *(See Instructions and Spaces I:or Additional Data on Reverse Side) INSTRUCTIONS General Th~s form ~s designed for submitting a complete and correct well complet.on report end log on all types of lanJs and leases ~n Alaska Item: 16 Indicate which elevation ~s used as reference (where not otherwise shown) for depth measure- ments g~ven ~n cther spaces on th~s form and ~n any attachments Items 20, and 22. If th~s well ~s completed for separatc production from more than one ~nterval zone (multiple completion), so state ~n ~tem 20, and~n ~tem 22 show the prcJuc~ng ~nterval, or ~ntervals, top(s), bottom(s) and name (s) (.f any) for only the ~nterval reported ~n ~tem 30 Submit a separate report (page) on th~s form, adequately ~dent~fied, for each additional ~nte~val to be seperately produced, show- ~ng the actld~t~onal data pertinent to such ~nterval Item26: "Sacks Cement" Attached supplemental records for th~s well shoulJ show the details of any mul- ,pie stage cementing and the location of the cemennng tool Item 28: Submit a separate completion report on th~s form for each ~nterval to be separately produced (See ~nstruchon for aems 20 and 22 above) r~ARY OF I~OTLMATION TW-RTb INCLUDIN(, INTERVAL TF_~TED PRESSURE DATA A2q~ '~OV~q~IE.S OF OIL GAS 35 G gOI...OG 1 C WAT~r~ AND MUD NAMlg , , E Pool 9050' 7531' F Pool 9435' 7818' G Pool 9715' 8060' DATA ATTACH BIllET DESCRIPITION$ OF LITHOLOGY POROSITY FRACTURES APPAJ~iE. NT DIPS AND I)EFEC'UEI) SHOWS OF OIL, GAS OR WATEIt PD 4A (Re~. 5-65) P~mted in U.S.A. . MIDDLE GROUND SHOAL KENAI (COUNTY} SH~LL OIL DR/I~ING RBPORT ~OR Pi!ILIOD November 30, 1967 Section 14 (,~ o~'L-E~.~-) - - : ' T8N, R13W DAY D£1:'TH$ ..... RKMARi<S FRO~i I TO ,,, Location: Conductor 30, Leg 4 @ 65.88' S & 49.28' E from center Leg 1 @ 1627' N & 435' W from S.E. corner Sec. 11, T8N, R13W, S.M. Elevation: Derrick floor 116' (MLLW) Nov. 1967 2 315 469 Spudded 4:30 A.M. 11/2/67. Drilled 15" hole to 469'. 3-4 469 1890 Drilled 15" hole to 1890' turbodrill #1 350-610' faced S5W. Circulated to run casing. 5 1890 _Cemented 1.0-3/4" casin~ ,at 1.871' with 1975 sacks. Ran 10-3/4", J-55 40.5#, Buttress casing with ~hoe at 1871' 'and 'fill up collar at 1828'. Pumped in 50 cu ft water ahead of 1300 sacks class G cement (103 pcf slurry) mixed with 10% Bentonite. Followed with 200 sacks class G cement (118 pcf slurry) mixed with inlet water. Displaced with 1037 cu ft mud. 6 1890 2818 Flanged up and tested BOPE with 1500 psi and Hydril with 1000 psi. Drilled 9-7/8" hole to 2818'; mud 69-72 pcf. 7-29 2818 10463 Drilled 9-7/8" hole to 10,444'. Mud 72-74 PCF. Turbodrill #2 2818-2918 Faced N85W - Turbodrill #3 3008-3228 Faced West Turbodrill #4 5472-5533 Faced N75W Turbodrill #5 8488-8533 Faced N80W Turbodrill #6 8681-8704 Faced N72W Stuck bottom stabilizer at 9890' worked free and drilled 9-7/8" hole to 10,463' reamed 9890-10,444. Nov. 29-30 10463 10533 Drilled 9-7/8" hole to 10,533'; ~an Dual Induction-Lsterolog Run 1 .~8.7.1' to 10.~.516'; Compen.s.ated Sonic 10g~ Run 1~ 6800'..to 10~51~.". Condition at End of Period , , 'HOLE ~mo s~z~ D~H s~ 15" 315 469 10-3/4 '1871 ' 9-7/8~'469 10~33 DRi~ PIP~ 5 ~ ~ _ SIZE~ ~ PD 4A (R%v..5-65) P;,ntecl m U.S.A. ~ $t"[~ OIL COiMIP,6-N~ (" w,'~.,.,o A-33-~4 MIDDLE GROUND SHOAL PORT Sec. 14 _KENAY December 2~ 1967 TSN R13~ DAY DEPTHS - ~,~o~' I, 'to , _ J~ : : ,., Dec. 1-2 10533 10555 Drilled 9-7/8" hole to 10,555. C.emen~t_e~d 7" casing at 10,531' with 1100 sacks. Ran 7" Buttress casing (23f~, N-80, surface to 6435-', 26f~ N-80, 6435-9831'; 29f~, N-80, 9831-10,531'), with super seal float shoe at 10,531' and self-fill differential collar at 10,487'. Cement with 1100 sacks class G (108slurry) mixed with 1% CFR-2. Displaced with 2320 ft3 of inlet water. Bumped plug with 2000 psi. Ran in with 6" bit and scrapper on 3-1/2" tubing. 3 PBTD 10487 Lost 6" bit in hole at 6596'. Attempted to screw on to fish. Fish fell to 7170'. Push bit to 10,427'. 4 PBTD 10487 Ran Ga~a Ray.-._.~ollar ~-.. Cement Bond Log ;~ Run 1, 670~'-10415'. Pushed fish to 10,484. 5 PBTD 10487 Ran 3-1/2" EUE, N-80 and J-55 Tubing to 9003', packer at 8939'. In- stalled tree and tested with 5000 psi. 6-7 PBTD 10487 Perforated through tubing with 4 shots/ft 9061-9083' 9435-9451' 9456-9472' 9715-9804' 9860-9888' 9954-9995' 10 008-10 162' 10,173-10,239' 10 261-10 302' 10,328-10,460' Placed well on gas lift. Rgleased rig 2:00 A.M. 12/7/67 , , , ' ,,. .... . , ..,.. , , .... ~ . .' , ,., ., , , ~;, . .:..,... CONDITION A~~F PERIOD .~ , , ,- , , , ~ - .,. , .. , , 15" 315 1890 10-3/4 1871' ' 9-7/8'~ 1890 D555 7" 10531' mz~s 3-1/2" ~ubing -- .... ., . ...... . .... ... · ..... , '., ,. , , ~ ~ , , , , , , ~-,., , .... · ),,_ MEAl' ' BEARING i LATITUDE DEPARTURE T0~TA L .~,,,-AS. ), VERTICAL DEPTH CUM. ' ' ~. -, I I LOSS iD~p i H[.STA. ANGLE · OF LATITUDE.: . .. DEPARTURE SECTION i40(~]DIS.T' COURSE TOTAL DEVIATION NORTHI! SOUTH EAST I WEST NORTH SOUTH EAST I WEST , , - , ....... WELL: /~-, 3'5- ) ~ SPUD DATE.: ELEV: l t-~ "P, t=', CALCU:LATED BY: SHEET: S:4ELL O~L CO. ~ ',~ ~ .... , ...... I ' t'! ' '' TOTAL '" BEARING LATITUDE DEPARTURE ~,,.:-^~ lr~r--A.. VERTICAL DEPTH GUM. ' ~'"=~' JSTA.i ANGLE , "" OF LATITUDE DEPARTURE SECTION 'Dr_PTH DIST,] COURSE TOTAL LOSS '- ['~~! 'i , ~ : ' DEVIATION NORTH SOUTH EAST m~,~ SOUTH m EAST '"EST .,.....,, , , , t9~o9 181 ,~o lSo;~??~Z4b 159bSZ ) ,, , , i WELL: A-BJ-14 , SPUD ;ATE: ..... ELEV: Jim'S, · SX LL CO. · ' BEARING I LATITUDE DEPARTURE TOTAL I .,.-,,o )IMEA. VERTICAL DEPTH CUM. ,, .~,' IISTA. j ANGLE ,, OF ~ LATITUDE DEPARTURE SECTIO ~'~7~'z~ ~' /o1~ ~ql ~7 zs~j~'~ s '~~ 7~ ol z 5~ 9ol S~~o ,!ELL: ~' '~':5- l g c- SPUD DATE: ELEV: II ~' C), F, CALCULATED BY: SHEET: :z'/z~' ,= ....... ' ....... ' ............ : -.~' ~ L** ~, ~ ~ ,'3 ~ , CO. ~.~..- 'i'L,~E'A. VERTICAL DEPTH BEARING LATITUDE. DEPARTURE -- TOTAL ~,..A;5. '.~ T~, , CUM LATITUDE DEPARTURE SECTION DEPTH ~i~. AN'OLE ,,, ' OF , , ~) L~ '" COURSE TOTAL LOSS DEVIATION NORTH SOUTH EAST WEST NORTH SOUTH EAST ~ ?/EST .... , , , i0o ~ o~g5' j~oo /oooc D g5 ~ ~7 o8 Csoq q897 ~o &o lo°od 5") ~ 7o'7 )o~ ¢q¢ s ¢ a ,.' 10135, ~i_ /o755 cz z~ q t 73 ~ , , ,, NF. LL: .n-5%-^ 14~ SPUD DATE: . - ELEV:, Ii(..o' F), F, _ CALCULATED BY: SHEET,~(~,~?~.~.-.. ; ..... , .... , ..... ~ . ,'~' '", ;,' - ~ ., , ' Form No P---4 REV 9-30-67 ( STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS SUBMIT IN DEPLICATE OIL ~ GAS ~-~ OTHER WELL -- WELL NAlVIE OF OP~TOR Shell Oil Company 3 AI~DRESS OF OPERATOR 430 Seventh Avenue, Anchorage, Alaska 99501 4 LOCA~ON OF WRTJ. Conductor 30, Leg 4, @ 65.88'S & 49.28'E from Leg 1 @ 1627'N & 435'W from SE corner, Section 11, T8N, R13W, S.M. API NL~{E~CAL CODE AP1 50-133-20057 6 LEASE DESiG.N'ATION AND SERIAL NO ADL 18756 IF INDIIN, .%LOTTEE OR TRIBE NAIIE 8 U!N'IT,FAI~%{ OR LEASE NA-AIE Middle Ground Shoal 9 WELL NO A- 33-14 10 FIEJ_J) A.ND POOL OR WILDCAT Middle Ground Shoal 11 SEC, T, R, M (BOTTOM HOI~E OBJECTIVE) Sec. 14~ T8N; R13W, S.M. ~ P~R/VIIT NO 67-68 13 RE. PORT TOTAL DEPTH AT END OF MONTH, CHA~TGES IN HOLE SI~E, CASING A_ND CE1ViENTING JOBS INCLUDING DEPTH SET AN~ VOLLrMES USED, PERFORATIONS. TESTS AND RESULTS, FISHING JOBS JIINK IN HOLE AND SIDE-TRACKED HOLE AND ANY OTHER SIGNIFICAI~T CILA_~GF~ IN HOI.~ CONDITIONS Spudded 4:30 a.m. 11-2-67. Drilled 15" hole to 1890'. Cemented 10-3/4" casing at 1871' with 1975 sacks. Drilled 9-7/8" hole to 10,555'. Ran logs. 14 I hereby ~ertlfy s~w~ Div~ Exploitation Engr, ~A'.,.,/, /~ NOTE--Report on th~s form ~s reqmred for each calendar month, regardless of the status of operat,ons, and must be filed m duphcate w~th the D~ws~on of Mines & Minerals by the 15th of the succeeding month, unless otherwise d~rected SHELL OIL COMPANY 430 7TH AVENUE ANCHORAGE. ALASKA 99501 December 4, 1967 Confidential Material STATE OF ALASKA 3001 Porcupine Drive Anchorage, Alaska Attention T.R. Marshall, Jr. Gentlemen: Enclosed are the Monthly Report of Operations (2 copies~~for November, 1967, for our Middle Ground Shoal wells, A-12-12,~-33-1J~and C-31-26o W~/mw Very truly yours, R.D. Allen Division Exploitation Engineer Enclosures SHELL OIL COMPANY 430 7th AVENUE ANCHORAGE, ALASKA 99501 November 7, 1967 SUBJECT: Middle Ground Shoal Field Well A-33-14 ADL 18756 State of Alaska Division of Land 344 Sixth Avenue Anchorage, Alaska Attention: Pedro Denton Gent ! emen: Please be advised that on November 2, 1967 Shell Oil Company, as operator, spudded development Well A-33-14 on State lease ADL 18756. The well will be directionally drilled to a location in the SE/4 of Section 1~ TSN, R13W, S.M. Very truly yours, ~- / ~'~ T.S. Cate Alaska Division Land Manager TSC/mm cc: Wes Hillman RECEIVED SHELL OIL COMPANY 430 7th AVENUE ANCHORAGE. ALASKA 99501 October 26, 1967 PRIVATE & CONFIDENTIAL STATE OF ALASKA Division of Mines & Minerals 3001 Porcupine Drive Anchorage, Alaska Attention: T.R. Marshall, Jr. Gent lemen: Enclosed for your approval is our Application for Permit to Drill Well SAS M.G.S. A-83-14. The well will be directionally drilled to bottom in the NW/4 of the SE/4 of Section 14, T8N, R13W~ S.M. Also enclosed is our check in the amount of $50.00 for the filing fee. Very truly yours~ R.D. Allen Division Exploitation Engineer Enclosures: Filing Fee Check (1) Application to Drill (3) Location Plat (3) Blowout Prevention Program (3) RECEIVED OCT g? 1987 DIVISION OF MINES & MINERAJ~ ANCHORAGE FORM SA - I B :~ 125 5M 8/67 j MEMORANDUM FROM: State of Alaska DATE : SUBJECTs FORM SA- I B 125 5M 8/67 MEMORANDUM TO= r- i~ll~iillllllI State of Alaska DATE : tjJjlJllI~ :~JJJt ~ SUBJECT, IjJJJj 'Jlllll~ ~ ,~JJ~JJ~ lIIiI eli eib, ~l~mii~ lei Form ~--1 STATE OF ALASKA ! SUBMIT IN TRI]~ ATE* (Other instructions on reverse side) AP1 50-133-20057 Effech~e July 1, 196~ OIL AND GAS CONSERVATION COMMITTEE APPLICATION FOR PERMIT TO DRILL, DEEPEN, OR PLUG BACK 1R. TYPE OF WORK DRILL J~ O,L [] GAs [] SINGLE[] 2, NAME OF OPERATOR Shell 0~1 Company ~. ADBRESS OF O~RATOR ~30 Seventh ~venue DEEPEN I-1 PLUG BACK [--I MULTIPLE ~_~ ZONE 4. LOCATZON OF WELL (Report location clearly and in accordance with any State_requirements.*) At surface Conductor 30, Leg 4 @ 65.88'S & 49.28'E from Leg 1 @ 1627'N & 435'W from SE corner Section 11, T8N, R13W, S.M. At proposed prod. zone *See Below 14. DISTANCE IN MILES AND DIRECTION FROM NEAREST TOWN OR POST OFFICE* 17 Miles NW Kenai~ Alaska LEASE DESIGNATION &ND SleRIAI, NO ADL 18756 6 IF INDIAN, ALLOTTEE OR TIIEE NAME None 7. UNIT AGREEMENT NAME None 8. FARM OR LEASE NAME Middle Ground Shoal 9 WELL NO, A-33-14 10 FIELD A,%rr) POOL, OR WILDCAT Middle Ground Shoal 11. SEC., T , R., M , OR BLK. AND SURVEY OR AREA Sec. 14, T8N, R13W, S.M. 12. BOROUGH SH J 13. STATE Kenai J Alaska DIBTANCE FROM PROPOBED* LOCATION TO NEAREST PROFRRTY OB LEASE LINE, FT. (AlJo to nearest drlg. unit line, if any) DISTANCE FaOM PaOPOSED LOCATION* TO NEAREST WELL, DRILLING, COMPLETED, OR A~PLIED FOB, ON THII~ LEASE, FT. 3700' 1200' 16. NO. OF ACRES IN LEASE 5120 ~9 PaoPosED D~PTH 10,500 ' 17. NO. OF ACRES ASSIGNED TO THIS WELL 8O 20 ROTARY OR CABI,E TOOLS Rot ary 21. EmVA~ONS (Show whether DF, RT, GR, etc.) 116' D.F. 22, APPROX, DATE WORK WILL STARTS 11-2-67 23. PROPOSED CASING AND CEMENTING PROGRAM SIZE OF HOLE SIZE OF CASING 15" !n-3/A" 9-7/8" 7" *Top 8g00+' WEIGHT PER FOOT 23_ 26_ 29 SETTING DEPTH !850' 10~500' QUANTITY OF CEMENT (TVD 7300±') 2700±'N & 1600±'W from the SE corner Sec. 14, T8N, R13W, SoM. Bottom 10,500±' (TVD 8800±') 1600±'N & 2000±'W from the SE corner Sec. 14, T8N, R13W, SoMo IN ABOVE SPACE DESCRIBE PROPOSED PROGRAM: If proposal 18 to deepen or plug back, give data on present productive zone and proposed new productive zone. If proposal is to drill or deepen directionally, give pertinent data on subsurface locations and measured and true vertical depth% Give blowout preventer program, if any. 24 I hereb~rt,fy that ih~or~rue and Correct. S,~NED'---' £~'~ ,f~ ~,.TITLE Division Exploitation Eng. (This space rot e State office use) CONDITIONS OF APPROVAL, IF ANY: APPROVAL DATE THOMAS R. MARSHALL, J~J, TITLE Execuhve Secrelary Ale:ks O,I & Oas Cor, ser¥otion CommffleQ I '/ RECEIVED AP1 50-133-20057 *See Instructions On Reverse Side 0Cl 27 1967 DIVlIlON OF MINER & MINERA~ · = ~ T. 8N., R13W., S.M. I .... 14 13 '1 .... A-11-13 I ' I ^DL ~e'~e ! -14 I I 33-14 I I I ~ I A-3 ~14 _ [ ~ 1413 ~ " 23~24' !' LOCATION OF CONBBCTOI 30, LEG ~ 4 LOCATION 0r PIIHCIflG ZONE WELL A-33.~4 PUBL lC LAND DESCRIPTI~ ~ONDU~TOR 30, LIG No 4 LOCATED 65.88'S 1600'N AND 2000'W AND 49.28'E FROM CENTER OF LEG No I FROM THE SE C~. CENTER LEG Ne 1 LOCATED 1627' N AND OF ~.C. 14, TON, R13W, S.M. 435'W FROM THE SE CON. OF SEC. II , , ~,,~K.'"',,~.~.'. - 5HELL OIL ~MPANY z2~-z21.~.~04 DATE: 26 OCT. 6~ - I r I IIIIIIIII II III _1 III I I II IIII I IIIIIII _1111 I , I III III I II I II1_1[11111 III LOCATION OF 6HELL-ATLANTIC-STANDARD WELL A.33 -14 IN ~C. 14 ~ T. IN., R.13W., ~M.- ~ INLET - ~ATE I IIIII IIII II IIIIIlllll I IIIIlllll IIIIIII II III I IIII I IIIIII II I I IIII I III IIII I I III I lib II DRILLING~ CASING~ AND BLOWOUT PREVENTION PROGRAM WELL A-33-14 MIDDLE GROUND SHOAL - PLATFORM "A" COOK INLET~ ALASKA 1. Move rig over 24" subconductor 30, Leg 4. Install 20" riser assembly° 2. Drill 15" hole to 1850±'. Run 1850±' of 10-3/4" 40°5# J-55 Buttress casing. Cement with 1500 sacks API cement° 3. Land casing and flange up 12" 3000 psi preventer stack consisting of Double Shaffer Gate and GoKo Hydrilo 4. Drill 9-7/8" hole to 10,500'o Run logs. Run 10,500±' of 7" 23#, 26#, and 29# Buttress casing° Cement with 1200 sacks API cement° 5. Run 3-1/2" 9°3# J-55 and N-80 EUE tubing string equipped with packers° Dis- place annulus above packers with inhibited Inlet water and displace tubing and annulus below packers with diesel oil. Set packers. 6° Perforate productive zone with 4 shots per foot at selected intervals° Place well on production. RJ 10/26/67 RECEIVED , OC1 g? 1967 OIVi$1ON OF MINES & MINERAL~ DRILLING~ CASING~ AND BLOWOUT PREVENTION PROGRAM WELL A- 33-14 MIDDLE GROUND SHOAL - PLATFORM "A" COOK INLET~ ALASKA 1. Move rig over 24" subconductor 30, Leg 4. Install 20" riser assembly° 2. Drill 15" hole to 1850+'. Run 1850+' of 10-3/4" 40°5# J-55 Buttress casing. Cement with 1500 sacks A_PI cement° 3. Land casing and flange up 12" 3000 psi preventer stack consisting of Double Shaffer Gate and GoKo Hydrilo 4. Drill 9-7/8" hql~_tp_10,500'o _gun_logs._ Run 10,500±' of 7" 23#, 26#, and 29# Buttress casing° Cement with 1200 sacks API cement° 5~-Run 3-t/2" 9°3# J-55 and N-80 EUE tubing--string equipped with packers° Dis- place annulus above packers with inhibited Inlet water and displace tubing and annulus below packers with diesel oil. Set packers. 6° Perforate productive zone with 4 shots per foot at selected intervals° Place well on production. RJ 10/26/67 RECEIVED , OCl 1967 DIVISION OF MINES & MtNERAL~
