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Home My WebLink About195-012STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS L . V a MAR `;; �i 119 1. Operations Abandon L Plug Perforations L Fracture Stimulate L Pull Tubing L Operations shutdown Performed: Suspend ❑ Perforate ❑� Other Stimulate ❑ Alter Casing ❑ Change Approved Program ❑ Plug for Rednll ❑ Perforate New Pool ❑ Repair Well ❑ Re-enter Susp Well ❑ ' Other: ❑ 2. Operator 4. Well Class Before Work: 5. Permit to Drill Number: Name: Hilcorp Alaska, LLC Development Exploratory ❑ Stratigraphic ❑ Service ❑ 195-012 3. Address: 3800 Centerpoint Drive, Suite 1400 6. API Number: Anchorage, AK 99503 50-733-20258-01-00 7. Property Designation (Lease Number): 8. Well Name and Number: ADL0018764 MGS A24-01 RD 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pool(s): N/A Middle Ground Shoal / E,F and G Oil 8 Middle Ground Shoal Oil Pools 11. Present Well Condition Summary: Total Depth measured 11,994 feel Plugs measured N/A feet true vertical 9,827 feet Junk measured N/A feet Effective Depth measured 11,941 feet Packer measured 9,824 feet true vertical 9,815 feet true vertical 8,572 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 370' 24" 370' 370' Surface 2,010' 13-3/8" 2,010' 1,830' 3,090 psi 1,540 psi Intermediate Production 10,013' 7" 10,013' 8,731' 8,160 psi 7,020 psi Liner 2,824' 5" 11,994' 9,805' 10,140 psi 10,490 psi Perforation depth Measured depth 9,965 - 11,784 feet True Vertical depth 8,690 - 9,780 feet 2-7/8" 6.5# / L-80 9,144 (MD) 8,014 (TVD) Tubing (size, grade, measured and true vertical depth) 2-3/8" 4.7 # / N-80 9,902 (MD) 8,637 (TVD) 9,824 (MD) 311 (MD) Packers and SSSV (type, measured and true vertical depth) Baker FH Packer 8,572 (TVD) Baker FV -6 TRSCSSV 311 (TVD) 12. Stimulation or cement squeeze summary: Intervals treated (measured): NIA Treatment descriptions including volumes used and final pressure: N/A 13 Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 26 13 58 766 98 Subsequent to operation: 31 10 66 773 98 14. Attachments (required per 20 AAC 25.070, 25.071, a 25.283) 15. Well Class after work: Daily Report of Well Operations Exploratory ❑ Development Service ❑ Stratigraphic ❑ 16. )A 11 Status after work: Oil ❑' Gas 11WDSPL LJ Copies of Logs and Surveys Run ❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP ❑ SPLUG ❑ 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 319-056 Authorized Name: Stan W. Golfs Contact Name: Dan Marlowe Authorized Title: Operations Manager Contact Email: dmadowe@hilcom.00m Signature: & Date: 3 rf S 119 Contact Phone: (907) 283-1329 Authorized 3-� /5 Form 10-404 Revised 4/2017 RBDMSAW MAR 0 6 2019 Submit Original Only Middle Ground Shoal Well: MGSIRD Completed: 5//11 Last ete SCHEMATIC PTD: 95 012d: 0/95 cora Akska. LU API: 50-733-20258-01 RKB: MSL =96' CASING DETAIL PBTD: 11,941' TD: 11,994' Size Wt Grade Conn ID Top Btm 24" 311' 2.310" Conductor Baker FV -6 TRSCSSV Surf 370' 13-3/8" 61 K-55 BTC 12.515 Surf 2,010' 7" 29 N-80 BTC 6.184 Surf 10,013'(KOP) 5" 18 L -80/P-110 STL 4.276 9,170' 11,994' TUBING DETAIL JEWELRY DETAIL No Depth (MD) Depth (TVD) ID OD Item 1 311' 311' 2.310" 4.625" Baker FV -6 TRSCSSV 2 2,095' 1,904' 2.441" 4.750" GLM #1 3 3,789' 3,390' 2.441" 4.750" GL0#2 4 5,132' 4,548' 2.441" 4.750" GUM #3 5 6,158' 5,397' 2.441" 4.750" GLM#4 6 6,867' 5,998' 2.441" 4.750" GLM #5 7 7,448' 6,510' 2.441" 4.750" GLM #6 8 7,998' 7,005' 2.441" 4.750" GLM #7 9 8,544' 7,502' 2.441" 4.75W GUM #8 10 9,097' 7,977' 2.441" 4.750" GLM #9 11 9,144' 8,014' 1.995" 3.668" 1 X -Over 2-7/8" to 2-3/8" 12 9,744' 8,505' 1.901" 3.850" GLM #10 %" (16) Orifice Valve 13 9,791' 8,544' 1.875" 2.375" OtisX Nipple 14 9,824' 8,572' 1.978" 1.978" Baker "FH' Packer 15 9,869' 8,609' 1.791" 2.375" Otis XN Nipple 16 9,902' 8,637' 11,548' 9,672' Modified Wireline Re-entry Guide PERFORATION DETAIL Top (MD) Btm (MD) Top (TVD) Btm (TVD) Fr Date Status 9,965' 10,025' 8,690' 8,742' 60' 07/19/2016- 07/20/2016 Open PHK-2 10,048' 10,073' 8,761' 8,783' 25' 03/11/2016 Open 10,075' 10,095' 8,785' 8,802' 20' 03/10/2016Open 10,135' 10,145' 8,836' 8,845' 30' 07/20/2016 Open HK -1 -HK -2 10,200' 10,242' 8,892' 8,929' 42' HK -2 10,254' 10,313' 8,939' 8,991' 59' 02/25/2019 Open HK -2 10,330' 10,406' 9,006' 9,073' 76' HK -2 10,426' 10,686' 9,090' 9,313' 260' HK -3 10,698' 10,714' 9,323' 9,336' 16' 02/25/2019 Open HK -2 10,790' 10,918' 9,396' 9,485' 128' HK -2 11,016' 11,187' 9,539' 9,611' 171' HK -2 11,358' 11,548' 9,672' 9,725' 190' HK -1 -HK -2 11,564' 11,610' 9,729' 9,741' 46' HKA 11,682' 11,713' 9,757' 9,764' 31' HKA 11,736' 11,784' 9,769' 9,780' 48' Updated By: JUL 02/26/19 BHilcorp Alaska, LLC Weekly Operations Summary Hilcorp Alaska. LLC Well Name Rig API Number Well Permit Number Start Date End Date MGS A24-01RD Eline 50-733-20258-01 1 195-012 2/24/2019 2/25/2019 Daily Operations: 02/24/19-Sunday E-Line crew arrived on platform and received orientation and room assignments. Held PJSM and talked about scope of work for afternoon. Walked down job with Crane Operator, E-Line Operator, and WSM. Spotted all E-Line equipment. M/U pump-in sub, lubricator, and W/L valve. Night Cap well. Cont. rigging up E-Line equip. Attempt to pressure test lubricator. Swap test pumps, still bleeding off. Determine issue to be swab valve. Grease swab, master, and wing valve. Pressure test lubricator to 3500 psi. Secure well and SDFN. 02/25/19 - Monday Hold PJSM and fill out work permits. M/U lubricator and grease head. M/U GR, CCL, E-Line Jars, and 16' of 19/16" retrievable tubing guns, 6 SPF 60 deg. phased, 3.2 gm Razor Charges. CCL is 16' above top shot. Pressure test lubricator and associated equipment to 250 psi low/ 3500 psi high in accordance with AOGCC approved sundry. RIH w/ well flowing to 10,800'. Log up to 10,000' and send to town for correlation. Drop correlation 4' per Geo. Perforate 10,698' to 10,714' =16'. Only indication of guns firing on surface is the loss of GR tool. Tubing pressure increase of 2psi from 75 psi to 77 psi. POOH. Unable to bleed off lubricator. Determine that guns are still across tree and a-line is unable to bump up. S/I W/L valve and SSSV to bleed off well. Pull lubricator and discover knot in cable. Cut and re-tie cable and POOH, all shots fired. Re-dress a-line equipment. M/U 20' of 19/16" retrievable tubing guns, 6 SPF 60 deg. phased, 3.2 gm Razor Charges. CCL is 13.5' above top shot. RIH w/ well flowing to 10,500'. Log up to 10,200' and send to town for correlation. Drop correlation 1' per Geo. Perforate 10.293'to 10,313'=20'. Good indication of guns firing on surface. No change in TB pressure=80psi. POOH, all shots fired. Remove E-Unejars due to lost continuity. M/U 20' of 19/16" retrievable tubing guns, 6 SPF 60 deg. phased, 3.2 gm Razor Charges. CCL is 7.2' above top shot. RIH w/ well flowing and correlate on depth. Perforate 10,273'to 10,293'=20'. Good indication of guns firing on surface. No change in TB pressure=78 psi. POOH, all shots fired. M/U 19' of 19/16" retrievable tubing guns, 6 SPF 60 deg. phased, 3.2 gm Razor Charges. CCL is 8.1' above top shot. RIH w/ well flowing and correlate on depth. Perforate 10,254' to 10,273' =19'. Good indication of guns firing on surface. No change in TB pressure=79 psi. POOH, all shots fired. L/D spent guns and lubricator. Night cap and secure well. SDFN. THE STATE °fALASKA GOVERNOR MIKE DUNLEAVY Stan W. Golis Operations Manager Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www.cogcc.olaska.gov Re: Middle Ground Shoal Field, E, F, and G and Middle Ground Shoal Oil Pools, MGS A24-01RD Permit to Drill Number: 195-012 Sundry Number: 319-056 Dear Mr. Golis: Enclosed is the approved application for the sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, CayFoerster Commissioner DATED this 7�day o f February, 2019. SCANNED -- ,,I ,',:n STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 07-5 '47/1l L _. 1. Type of Request: Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Repair Well ❑ Operations shutdown ❑ Suspend ❑ Perforate Q • Other Stimulate ❑ Pull Tubing ❑ Change Approved Program ❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other: ❑ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: Hilcorp Alaska, LLC Exploratory ❑ Development Q. Stratigraphic ❑ Service ❑ 195-012 3. Address: 3800 Centerpoint Drive, Suite 1400 6. API Number: Anchorage, AK 99503 50-733-20258-01-00 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? CO 44A ' Will planned perforations require a spacing exception? Yes ❑ No 0 MGS A24-01 RD . 9. Property Designation (Lease Number): 10. Field/Pool(s): ADL0018754 I Middle Ground Shoal / E,F and G Oil and Middle Ground Shoal Oil Pools 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth ND (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): 11,994 • 9,827 11,941 9,815—100psi N/A N/A Casing Length Size MD ND Burst Collapse Structural Conductor 370' 24" 370' 370' Surface 2,010' 13-3/8" 2,010' 1,830' 3,090 psi 1,540 psi Intermediate Production 10,013' 7" 10,013' 8,731' 8,160 psi 7,020 psi Liner 2,824' S" 11,994' 9,805' 10,140 psi 10,490 psi Perforation Depth MD (ft): Perforation Depth ND (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 9,965 - 11,784 8,690 - 9,780 2-7/8" & 2-3/8" 6.5# L-80 & 4.7# N-80 9,144 & 9,902 Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft): Baker FH Packer & Baker FV -6 TRSCSSV 9,824 (MD) 8,572 (ND) & 311 (MD) 311 (TVD) 12. Attachments: Proposal Summary Q Wellbore schematic 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic ❑ Development ❑� ' Service ❑ 14. Estimated Dale for 15. Well Status after proposed work: Commencing Operations: 3/1/2019 OIL ❑� ` WINJ ❑ WDSPL ❑ Suspended ❑ GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ 16. Verbal Approval: Date: Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. 1 hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Authorized Name: Stan W. Golis Contact Name: Dan Marlowe Authorized Title: Operations Manager Contact Email: dmarigwe@_hilcorg.com Contact Phone: (907) 283-1329 Authorized Signature: Date: Z- 'l COMMISSION USE ONLY Conditions of approval: Notify Commission so trQt a representative may witness Sundry Number: /`"11 ()Gv) Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test El Location Clearance Other: Post Initial Injection MIT Req'd? Yes ❑ No ❑ `�, Spacing Exception Required? Yes ❑ No 1❑� Subsequent Form Required: p — ! Q y RBDMS*-�NFEB 0 7 2019 APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: Z Form 10-403 Revised 4/2017 - 11 sub�z ;-- �1�sin Form and PProvd aPPlicatioaORIGINAL approval. Attachments in Duplicate U Hiles p Alaska, LLC Well Prognosis Well Name: MGS A24-01RD API Number: 50-733-20258-01 Current Status: Gas -Lifted producer Leg: Leg #4 (West) Estimated Start Date: March 01, 2019 Rig: N/A (E -Line) Reg. Approval Req'd? 403 Date Reg. Approval Rec'vd: Regulatory Contact: Juanita Lovett (8332) Permit to Drill Number: 195-012 First Call Engineer: Dan Marlowe (907)283-1 329 (0) (907) 398-9904 (M) Second Call Engineer: Mike Quick (907) 777-8442 (0) (907) 317-2969 (M) Current Bottom Hole Pressure: Maximum Expected BHP: Maximum Potential Surface Pressure: Brief Well Summary 2,538 psi @ 8,000' TVD 0.330 psi/ft datum 2016 PBU 4,000 psi @ 8,000' TVD 0.490 psi/ft datum upper zone/offsets -100 psi Well to be perforated while flowing Well Middle Ground Shoal A24-01RD is a gas -lifted oil well completed in the Hemlock zone. This project will add Hemlock sands not currently perforated. HK -Z 14 IL E -line Procedure: 1. MIRU E -line, PT lubricator to 3,500 psi Hi 250 Low. 2. RU a -line guns and perforate per program. Record tubing pressures before and after perforating run. 3. RD E -line. 4. Turn well over to production. Attachments: 1. Current Wellbore Schematic 2. Proposed Wellbore Schematic HSCHEMATIC Hikora Alaska, LLC RKB: MSL = 96 PBTD: 11,941' TD: 11,994' Middle Ground Shoal Well: MGS A24-01RD Last Completed: 5/10/95 PTD: 195-012 API: 50-733-20258-01 CASING DETAIL Size Depth (MD) Grade Conn ID Top Btm 24" 311' 2.310" Conductor Baker FV -6 TRSCSSV Surf 370' 13-3/8" a29 K-55 BTC 12.515 Surf 2,010' 7" 4.750" N-80 BTC6.184Surf 5,132' 4,548' 10,013' (KOP) 5"80/P-110 GLM #3 5 STL 4.276 9,170' 11,994' TUBING DETAIL 2-7/8" 6.5 L-80 8rd 2.441 Surf 9,144' 2-3/8" 4.7 N-80 8rd 1.995 9,144' 9,902' JEWELRY DETAIL No Depth (MD) Depth (TVD) ID OD Item 1 311' 311' 2.310" 4.625" Baker FV -6 TRSCSSV 2 2,095' 1,904' 2.441" 4.750" GLM#1 3 3,789' 3,390' 2.441" 4.750" GLM #2 4 5,132' 4,548' 2.441" 4.750" GLM #3 5 6,158' 5,397' 2.441" 4.750" GLM#4 6 6,867' 5,998' 2.441" 4.750" GLM#5 7 7,448' 6,510' 2.441" 4.750" GLM#6 8 7,998' 7,005' 2.441" 4.750" GLM#7 9 8,544' 7,502' 2.441" 4.750" GLM #8 10 9,097' 7,977' 2.441" 4.750" GLM#9 11 9,144' 8,014' 1.995" 3.668" X -Over 2-7/8" to 2-3/8" 12 9,744' 8,505' 1.901" 3.850" GUM #10 Y.'(16) Orifice Valve 13 9,791' 8,544' 1.875" 2.375" Otis X Nipple 14 9,824' 8,572' 1.978" 1.978" Baker"FH" Packer 15 9,869' 8,609' 1.791" 2.375" Otis XN Nipple 16 9,902' 8,637' Modified Wireline Re-entry Guide PERFORATION DETAIL Zone Top (MD) Stm (MO) Top (TVD) Btm ( FT Date Status HK -2 9,965' 10,025' 8,690' 8,742' 60' 07/19/2016- 07/20/2016 Open HK -2 10,048' 10,073' 8,761' 8,783' 25' 03/11/2016 Open HK -2 10,075' 10,095' 8,785' 8,802' 20' 03/10/2016 Open HK -2 10,135' 10,145' 8,836' 8,845' 30' 07/20/2016 Open HK -1 -HK -2 10,200' 10,242' 8,892' 8,929' 42' HK -2 10,330' • 10,406' 9,006' 9,073' 1 76' HK -2 10,426' 10,686' 9,090' 9,313' 260' HK -2 10,790' 10,918' 9,396' 9,485' 128' HK -2 11,016' 11,187' 9,539' 9,611' 171' HK -2 11,358' 11,548' 9,672' 9,725' 190' HK -1 -HK -2 11,564' i 11,610' 9,729' 9,741' 46' HK -1 11,682' 11,713' 9,757' 9,764' 31' HK -1 11,736' 11,784' 9,769' 9,780' 48' Updated By: J1104/27/18 Middle Ground Shoal Well: MGSomp A24-eted: SRD /1 PROPOSED Last Completed: 5/10/95 PTD: 195-012 E ilwra Alaska, 1.1.0 API: 50-733-20258-01 RKB:MSL=9G CASING DETAIL PBTD: 11,941' TD: 11,994' le e/ Size Wt Grade I Conn ID Top Btm 24" 311' 2.310" Conductor Baker FV -6 TRSCSSV Surf 370' 13-3/8" 61 K-55 BTC 12.515 Surf 2,010' 7" 29 N-80 BTC 6.184 Surf 10,013' (KOP) 5" 18 L -80/P-110 STL 4.276 9,170' 11,994' TUBING DETAIL 2-7/8" 6.5 L-80 8rd 2.441 Surf 9,144' 2-3/8" 4.7 N-80 8rd 1.995 9,144' 9,902' JEWELRY DETAIL No Depth (MD) Depth (ND) ID OD Item 1 311' 311' 2.310" 4.625" Baker FV -6 TRSCSSV 2 2,095' 1,904' 2.441" 4.750" GUM #1 3 3,789' 3,390' 2.441" 4.750" GLM #2 4 5,132' 4,548' 2.441" 4.750" GLM #3 5 6,158' 5,397' 2.441" 4.750" GLM #4 6 6,867' 5,998' 2.441" 4.750" GLM #5 7 7,448' 6,510' 2.441" 4.750" GUM #6 8 7,998' 7,005' 2.441" 4.750" GLM #7 9 8,544' 7,502' 2.441" 4.750" GLM #8 10 9,097' 7,977' 2.441" 4.750" GLM #9 11 9,144' 8,014' 1.995" 3.668" X -Over 2-7/8" to 2-3/8" 12 9,744' 8,505' 1.901" 3.850" GLM #10 Y" (16) Orifice Valve 13 9,791' 8,544' 1.875" 2.375" Otis X Nipple 14 9,824' 8,572' 1.978" 1.978" Baker"FH" Packer 15 9,869' 8,609' 1.791" 2.375" Otis XN Nipple 16 9,902' 8,637' HK -1 11,682' Modified Wireline Re-entry Guide PERFORATION DETAIL Zone Top (MD) Btm (MD) Top (ND) (TVD) FT Date Status HK -2 9,965' 10,025' 8,690' 8,742' 60' 07/19/2016- 07/20/2016 Open HK -2 10,048' 10,073' 8,761' 8,783' 25' 03/11/2016 Open HK -2 10,075' 10,095' 8,785' 8,802' 20' 03/10/2016 Open HK -2 10,135' 10,145' 8,836' 8,845' 10' 07/20/2016 Open HK -1 -HK -2 10,200' 10,242' 8,892' 8,929' 42' HK -2 ±10,254' ±10,313' ±8,939' ±8,991' ±59' Future Proposed HK -2 10,330' 10,406' 9,006' 9,073' 76' HK -2 10,426' 10,686' 9,090' 9,313' 260' HK -3 ±10,698' ±10,714' ±9,323' ±9,336' ±16' Future Proposed HK -2 10,790' 10,918' 9,396' 9,485' 128' HK -2 11,016' 11,187' 9,539' 9,611' 171' HK -2 11,358' 11,548' 9,672' 9,725' 190' HK -1 -HK -2 11,564' 11,610' 9,729' 9,741' 46' HK -1 11,682' 11,713' 9,757' 9,764' 31' HK -1 11,736' 11,784' 9,769' 9,780' 48' Updated By:JLL01/30/19 i • Schwartz, Guy L (DOA) From: Schwartz, Guy L(DOA) Sent: Friday,April 07, 2017 8:45 AM To: Juanita Lovett Cc: Dan Marlowe;samantha.carlisle@alaska.gov Subject: RE:Withdraw Sundry#316-456/PTD: 195-012/MGS A24-01LE (Recently renamed MGS A24-01RD) Juanita, The AOGCC will withdraw sundry#316-456 as requested below. Guy Schwartz Sr. Petroleum Engineer AOGCC 907-301-4533 cell 907-793-1226 office CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission (AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information.The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail,please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Guy Schwartz at(907-793-1226) or(Guy.schwartz@alaska.gov). From:Juanita Lovett [mailto:jlovett@hilcorp.com] Sent:Thursday,April 06,2017 10:07 AM To:Schwartz,Guy L(DOA)<guy.schwartz@alaska.gov> Cc:Dan Marlowe<dmarlowe@hilcorp.com> Subject:Withdraw Sundry#316-456/PTD: 195-012/MGS A24-01LE(Recently renamed MGS A24-01RD) Guy, Please withdraw the above mentioned sundry. The project will not be completed at this time. Scope of work was to recover the tubing,set a plug above the Hemlock(G sands), recompleting as an F sands producer. Regards, Juanita Lovett Operations/Regulatory Tech Hilcorp Alaska,LLC 3800 Centerpoint Drive Suite 1400 Anchorage,AK 99503 SCANNEV MAY () 9 2017 Office: (907)777-8332 ' Email: ilovett@hilcorp.com 1 RBDMS VL- " Y - 4 2017 • • From: Patricia Bettis To: Well History File: PTD 195-012 Date: January 13, 2017 Re: Well Name Change At the request of Hilcorp, the well name for MGS A24-01LE was changed to MGS A24-01RD, effective January 13, 2017. �4 , JAN 2 6 2017, • • OF TMJ • e,`,1 yy��i.e THE STATE Alaska Oil and Gas of LAsKA Conservation Commission __ _ A ft itt 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 *�' Main: 907.279.1433 (4' ALAS-1°' Fax: 907.276.7542 www.aogcc.alaska.gov Stan W. Golis Operations Manager Hilcorp Alaska, LLC SCANNED FEB 5 2017, 3800 Centerpoint Dr., Ste. 1400 Anchorage,AK 99503 Re: Middle Ground Shoal Field, E, F, and G Oil Pools, MGS A24-01 LE Permit to Drill Number: 195-012 Sundry Number: 316-456 Dear Mr. Golis: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Cathy . Foerster Chair DATED this 2-1' y of September,2016. RBDMS 1,BSEP 2 9 2016 S 0 RECEIVED STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION SEP 0 6 2016 APPLICATION FOR SUNDRY APPROVALS 47S j(27 l6. 20 AAC 25.280 C 1.Type of Request: Abandon ❑ Plug Perforations Cl Fracture Stimulate ❑ Repair WeN ❑ Operations shutdown ❑ Suspend ❑ Perforate I] / Other Stimulate ❑ Pull Tubing 0 ' Change Approved Program ❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other: Run GA.Completion 0 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number: Hilcorp Alaska,LLC • Exploratory ❑ Development 0 195-012 ' 3.Address: 3800 Centerpoint Drive,Suite 1400 Stratigraphic ❑ Service ❑ 6.API Number: Anchorage,AK 99503 50-733-20258-01 . 7.If perforating: 8.Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? CO 44'"- Will Will planned perforations require a spacing exception? Yes ❑ No 0 I MGS A24-01LE ' 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL0018754 • Middle Ground Shoal/E,F and G Oil Pools • 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP(psi): Plugs(MD): Junk(MD): 11,994 • 9,827 • 11,941' 9,815 • 3,134 psi N/A N/A Casing Length Size MD TVD Burst Collapse Structural Conductor 370' 24" 370' 370' Surface 2,010' 13-3/8" 2,010' 1,830' 3,090 psi 1,540 psi Intermediate Production 10,013' 7" 10,013' 8,731' 8,160 psi 7,020 psi Liner 2,811' 5" 11,994' 9,805' 10,140 psi 10,490 psi Perforation Depth MD(ft): Perforation Depth ND(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 9,965-11,784 • 8,690-9,780 2-7/8" 6.5#/L-80 9,144' 2-3/8" 4.7#/N-80 9,902' Packers and SSSV Type: Packers and SSSV MD(ft)and ND(It): Baker FH Packer&Baker FV-6 TRSCSSV ' 9,824'(MD)8,572'(ND)&311'(MD)311'(TVD) 12.Attachments: Proposal Summary 0 Wellbore schematic 0 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch 0 Exploratory ❑ Stratigraphic❑ Development 0 ` Service ❑ 14.Estimated Date for 15.Well Status after proposed work: Commencing Operations: 10/1/2016 OIL 0 ' WINJ ❑ WDSPL ❑ Suspended 0 16.Verbal Approval: Date: GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17.I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Contact Dan Marlowe(907)283-1329 Email dmarlowenhilcorD.com Printed Name Stan W.Golis Title Operations Manager Signature I.J Phone (907)777-8356 Date 9 ( G / i 4 COMMISSION USE ONLY Conditions of approval: Notify Commis ion so that a representative may witness Sundry Number: Plug Integrity ❑ BOP Test i Mechanical Integrity Test ❑ Location Clearance ❑ Other: / 3 Sc 7 p se Qh to ,C s i— (,-1V-- ci t`z_. I 6 Post Initial Injection MIT Req'd? Yes ❑ No ❑ Spacing Exception Required? Yes ❑ No [iii/ Subsequent Form Required: i 0 _ t[1 *o � RBDMS (,V SES' L 9 2016 APPROVED BY Approved by: _ COMMISSIONER THE COMMISSION Date:q-Z 7—/,s 94 i 7.f1c. ,4 �4' i.2E..� - Submit Form and Form 10-403 Revised 11/2015 0 . 1PGidthi4L8 valid for 12 months from the date of approval. Attachments in Duplicate Well Prognosis Well: MGS A24-01LE Hileorp Date: 09/01/2016 Well Name: MGS A24-01LE API Number: 50-733-20258-01 Current Status: Gas-Lifted producer Leg: Leg#4 South corner Estimated Start Date: 10/01/2016 Rig: AL,4 Ljo Reg.Approval Req'd? 403 Date Reg. Approval Rec'vd: Regulatory Contact: Juanita Lovett (8332) Permit to Drill Number: 195-012 First Call Engineer: Dan Marlowe (907) 283-1329 (0) (907) 398-9904 (M) Second Call Engineer: Stan Golis (907) 777-8356 (0) Current Bottom Hole Pressure: 4,345 psi @ 8,690'TVD 0.500 lbs/ft(9.62 ppg) Maximum Expected BHP(Hemlock): 4,345 psi @ 8,690'TVD 0.500 lbs/ft(9.62 ppg)Current Hemlock Sands Maximum Expected BHP(F Sands): 3,977 psi @ 8,437'TVD 0.471 lbs/ft(9.07 ppg)Proposed F Sands Maximum Potential Surface Pressure:3,134 psi Using 0.1 psi/ft gradient 20 MC 25.280(b)(4) Brief Well Summary The Middle Ground Shoal A-24-01LE is currently producing from the Hemlock benches 1 and 2 This workover will recover the tubing, set a plug above the hemlock(G sands), recompleting as an F Sands producer yet leaving the option to comingle the hemlock later. Brief Procedure: c)C"1. MIRU Rig. h'�""`cam 2. Well Kill operations: a) Set tubing plug in XN Nipple at 9,869'. b) Pressure test to 1,500psig and chart for 30 minutes. c) Punch and/or cut tubing in middle of full joint at±9,775'. d) Circulate well clean w/6%KCL—will be isolated from reservoir until perforating. 3. Notify AOGCC 48 hours before pending BOPE test. Set BPV, ND tree, NU BOPE.Test all BOP equipment per AOGCC guidelines to 250psi low andel igh. 4. Monitor well to ensure it is static, BOP's will be closed as need tE circulate the well. 5. Unseat hanger and POOH with production tubing. . ' 6. Cleanout to top of tubing stub±9,775', Circulate Clean, POOH. �'� 7. RIH w/ TCP guns and perforate per;preg m, Circulate and weight up as needed to balance well, ¢ + 7 estimated fluid weight requirec�9.07pp�gine, POOH. � � �>c, 8. Run production packer and gas--Impletion with live valves, s are out an aland completion, , stabbing over lower tubing stub with overshot. du�s1-tv 9. Pressure test completion: a. Test tubing against plug to 2500#and chart for 30 minutes. b. Test IA to 1,500 psi and chart for 30 minutes(This will pressure up tubing also). 10. Set BPV. NU tree,test same. 11. Turn well over to production. 12. Conduct SVS tests per AOGCC regulations. Attachments: 1. Well Schematic Current 2. Well Schematic Proposed Well Prognosis Well: MGS A24-01LE Hileorp Alaska,LLC Date: 09/01/2016 3. Wellhead Schematic Current 4. Wellhead Schematic Proposed 5. BOP Drawing 6. Fluid Flow Diagrams 7. RWO Sundry Revision Change Form • al Middle ll:MGS GroundA24-01ShoalLE We 11 SCHEMATIC Last PTD: 195 0112 d: 5/10/95 Hilrora Alaska.LLC API: 50-733-20258-01 RKB:MSL=96' CASING DETAIL 1A 1 I Size Wt Grade Conn ID Top Btm 24" Conductor Surf 370' 24" '; 13-3/8" 61 K-55 BTC 12.515 Surf 2,010' 7" 29 N-80 BTC 6.184 Surf (KOP) 13-3/8"''' 5" 18 L-80/P-110 STL 4.276 9,170' 11,994' (___: TUBING DETAIL 2-7/8" 6.5 L-80 8rd 2.441 Surf 9,144' 2-3/8" 4.7 N-80 8rd 1.995 9,144' 9,902' R 2-10 PFn JEWELRY DETAIL No Depth DepthIII ID OD Item (MD) (TVD) 1 311' 311' 2.310" 4.625" Baker FV-6 TRSCSSV D 2 2,095' 1,904' 2.441" 4.750" GLM#1 3 3,789' 3,390' 2.441" 4.750" GLM#2 0 4 5,132' 4,548' 2.441" 4.750" GLM#3 5 6,158' 5,397' _ 2.441" 4.750" GLM#4 6 6,867' 5,998' 2.441" 4.750" GLM#5 ill 7 7,448' 6,510' 2.441" 4.750" GLM#6 Top of liner8 7,998' 7,005' 2.441" 4.750" GLM#7 @9,170' g 11 ' 9 8,544' 7,502' 2.441" 4.750" GLM#8 10 9,097' 7,977' 2.441" 4.750" _ GLM#9 11 9,144' 8,014' 1.995" 3.668" X-Over 2-7/8"to 2-3/8" 12 9,744' 8,505' 1.901" 3.850" GLM#10 'A"(16)Orifice Valve 13 9,791' 8,544' 1.875" 2.375" Otis X Nipple 14 9,824' 8,572' 1.978" 1.978" Baker"FH"Packer 15 9,869' 8,609' 1.791" 2.375" Otis XN Nipple 16 9,902' 8,637' Modified Wireline Re-entry Guide 12 13 x PERFORATION DETAIL 14 MI 15 1s Zone Top(MD) Btm(MD) Top(TVD) (rvp) FT Date Status 9/1 7' 4 • H2 9,965' 10,025' 8,690' 8,742' 60 ��016 Open H2 10,048' 10,073' 8,761' 8,783' 25' 3/11/2016 Open H2 10,075' 10,095' 8,785' 8,802' 20' 3/10/2016 Open H2 10,135' 10,145' 8,836' 8,845' 10' 7/20/16 Open H1-H2 10,200' 10,242' 8,892' 8,929' 42' H2 10,330' 10,406' 9,006' 9,073' 76' - H2 10,426' 10,686' 9,090' 9,313' 260' H2 10,790' 10,918' 9,396' 9,485' 128' H2 11,016' 11,187' 9,539' 9,611' 171' - H2 11,358' 11,548' 9,672' 9,725' 190' H1-H2 11,564' 11,610' 9,729' 9,741' 46' H1 11,682' 11,713' 9,757' 9,764' 31' 5, 41 ‘ H1 11,736' 11,784' 9,769' 9,780' 48' PBTD:11,941' TD:11,994' Updated By:JLL 08/11/16 0 • WMidell:dleMGS Ground Shoal A24 01LE PROPOSED Last Completed: Future PTD:195-012 Hilcorp Alaska,LLC API: 50-733-20258-01 RKB:MSL=96' CASING DETAIL w. Size Wt Grade Conn ID Top Btm _ I 24" Conductor Surf 370' 24" r< 13-3/8" 61 K-55 BTC 12.515 Surf 2,010' 44i 0 1 7" 29 N-80 BTC 6.184 Surf 1(KOP) 13-3/8" 5" 18 L-80/P-110 STL 4.276 9,170' 11,994' It TUBING DETAIL P 2-7/8" 6.5 L-80 8rd EUE 2.441" Surf ±9,100' III 2-7/8" 4.7 L-80 8rd EUE 1.995" ±9,100' ±9,775' 2-3/8" 4.7 N-80 8rd EUE 1.995" ±9,775' 9,902' maa 2-9' JEWELRY DETAIL No Depth Depth ID OD Item (MD) (ND) 1 ±350' ±350' SSSV 2 ±1,974' ±1,800' 2.441" GLM#1 III 3 ±3,685' ±3,300' 2.441" GLM#2 4 ±5,068' ±4,500' 2.441" GLM#3 INF 5 ±6,153' ±5,400' 2.441" GLM#4 6 ±6,977' ±6,100' 2.441" GLM#5 Top of liner q 7 ±7,650' ±6,700' 2.441" GLM#6 8 ±8,213' ±7,200' 2.441" GLM#7 @9,170 g 1111 10.2g 9 ±8,773' ±7,700' 2.441" GLM#8 10 ±9,100 ±7,977' 1.995" 2-7/8"x 2-3/8"crossover 11 ±9,374' ±8,200' 1.995" 3.875" GLM#9 Orifice 12 ±9,470' ±8,278' 1.995" 3.750" Chemical Injection Mandrel 11 13 ±9,500' ±8,303' Packer st 12 14 ±9,745' ±8,505' Sliding Sleeve 13 t' 15 ±9,775' ±8,530' 2-3/8"Sealing Overshot ')It ±9,775' ±8,530' Top of cut tubing 9,791' 8,544' 1.875" X Nipple 14 9,824' 8,572' Baker"FH"Packer 1i 9,869' 8,609' 1.791" XN Nipple w/plug 1i 15 9,902' 8,637' Modified Wireline Re-entry Guide 12 II PERFORATION DETAIL Zone Top Btm Top Btm FT Date Status y, (MD) (MD) (TVD) (TVD) • F 9,663' 9,720' 8,437' 8,484' 57' Future Proposed H2 9,965' 10,025' 8,690' 8,742' 60' 7/19-20/16 Proposed Isolation H2 10,048' 10,073' 8,761' 8,783' 25' 3/11/2016 Proposed Isolation H2 10,075' 10,095' 8,785' 8,802' 20' 3/10/2016 Proposed Isolation - (4 H2 10,135' 10,145' 8,836' 8,845' 10' 7/20/16 Proposed Isolation H1-H2 10,200' 10,242' 8,892' 8,929' 42' Proposed Isolation H2 10,330' 10,406' 9,006' 9,073' 76' Proposed Isolation H2 10,426' 10,686' 9,090' 9,313' 260' Proposed Isolation H2 10,790' 10,918' 9,396' 9,485' 128' Proposed Isolation - H2 11,016' 11,187' 9,539' 9,611' 171' Proposed Isolation H2 11,358' 11,548' 9,672' 9,725' 190' Proposed Isolation H1-H2 11,564' 11,610' 9,729' 9,741' 46' Proposed Isolation PBTD:11,941' TD:11,994' H1 11,682' 11,713' 9,757' 9,764' 31' Proposed Isolation H1 11,736' 11,784' 9,769' 9,780' 48' Proposed Isolation Updated Sy:JLL 09/06/16 4110 . r Platform A v/ • ll Well 24-01LE 09/02/2016 II ileo p %I...kJ.LILL. Platform A Tubing hanger,CIW-AP-FBB, 24-01LE 11"x 3 1/2 EUE lift and susp, 133/8x7x27/8 w/3"type H BPV profile,1- 1/8 npt non continuous control line port BHTA,CIW,External knock-up,3 1/8 5M FE i r1iiII r_ 1 (-97'11 1, Valve,SSV,WKM,2 1/16 5M y 41 FE,w/13"Axelson, ® EE trim Tree,Block,CIW-F,11 5M FE \ ®0 x 3 1/8 5M x 2 1/16 5M wing, ®O 1 . EE trim,prepped f/6'/.ENri and'A npt control line exit "Fa. i LeirE \ / i i Tubing head,CIW-AP, -A-il I. 1\ / 4 Mill - 13 5/8 3M x 11 5M,w/2- 2 1/16 SM SSO,X bottom IIIII III Valve,CIW,2 1/16 5M,HWO prep OO J k G O4 i )U • I _ cL" I • Casing head,CIW-WF, .1 13 5/8 3M FE top x 13 3/8 _^ �� Valve,CIW-F,2 1/16 3M, SOW btm,w/2-2 1/16 SM III1 HWO EFO JI • i i i i� i ■ (C.-) 11 llMa.: r LI ■1 li - i •i_i t '• .ia i I 1! 133/8" 7" 2 7/8" • • Platform A .11 Well 24-01LE Proposed n,l.„,h tl.,.a.,.i.rt 09/02/2016 Platform A Tubing hanger,CIW-AP-FBB, 24-01LE 11”x 2 7/8 EUE lift and susp, 13 3/8 x 7 x 2 7/8 w/2 1/2"type H BPV profile, 2-1/2 npt continuous control line ports BHTA,Bowen,2 9/16 5M FE x 3"Bowen quick union 0 r Mina 1 A4 44,Valve,Swab,WKM-M, �O �J, O, �i� 2 9/16 5M FE,HWO,EE trim '{Iii 1V'' 'r o,�'o<C' IU Grp 40v<14‘ ��\F sat Q 4 0 0 iryert_tiltart 1.'$' 4.6 4',�., O N. /—) • ,A, ; , ,, \ 4y© i 4 / \ w Valve,Master,WKM-M, 0 O 2 9/16 5M FE,HWO,EE trim t. ni II (.li ,••�• milt_tilt tilt r� 4. , '1. ire' rt ,�. — 1 1 u 1 Tubing head,CIW-AP, _.jIl� 1t�II6 " / '�i�OUlI!U= 135/83Mx115M,w/2- 1 2 1/16 5M SSO,X bottom Valve,CIW,2 1/16 5M,HWO prep T i co i IIS i Z. 4.<0o ■ i • 0 0 �••// ■ Casing head,CIW-WF, li, 9F 13 5/8 3M FE top x 13 3/8 /116 Valve,CIW-F,2 1/16 3M, SOW btm,w/2-2 1/16 5M HWO EFO _ 114111 _ pp . •it %I 1 - R ' .4j �. 1 la ',:I 5 �I • �° e III 13 3/8" 7" 2 7/8" 11 S Platform A 2016 BOP Stack-workovers 09/01/2016 11 1cnrp:Ilacka_1.1,t. v v rflt i 3.74' Shaffer 13 5/8 5M I I iii iii iii di III Itl it 1 1 iti (� I CIW-U - `-s�0 Variable 27/8-5 and l_ O H,.� 23/8 rams 4.67' ` � ® J"ypp,, _. 13 5/8-5000 ra Blind Rams L O O O fill rf11 rffi ali i Choke and Kill Valves 2 1/16 5M w/Unibolt connections for hoses Art* 'Th\LH-RURUAti-M-1 2.00' I{ -)P.I 13 5/8-5000 !if i ILITTIRITTITTUr Riser,13 5/8 5M FE X 13 5/8 SM FE (1111 rftrill rf DSA,13 5/8 5M x 11 5M v 0 V - � 0 0 U O U 00 : 0 O u u 0 u 0 u u 0 u u �,�O O Q. 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C L j al 0 al al w 0 al a) al al a) ' E E E E E = = U L t t t t t t t t t z q 0 > 2 d 2 0_ O. X X S U U U U U V U U U V N 2 to a vY w v G .a w O N T 1100 . m O v1 f 2 z 4k 11 1/ N 0) N . CO . 4k In . (O O . U LB J a ccw I aw W N) . -4- Z0 OU 2U I �> UQ K => O I OJ aO /.(/ w o_w< N ■ .0 9 w w 1 : ,•• Y iii+iii T oQ m , w a H a 0 z a H u) Q J D z Z o Z � w anz Q o J (n J z ❑ _ a � Q oCCOU QQ � � O�, 3w , CD < oOcZ U -, OJ D4 D4 _ 0 ° 2 Z 1 2Dr2 H r JOO in u) . a Lu 01- LL Z a 0m z U' H Z o a' 5 I-- 1 P4 D U Ct 0 • Moncla Rig 404 BOP Test Procedure 410 Hilcorp aia.ka,i.i,c Attachment#1 Attachment #1 Hilcorp Alaska, LLC - BOP Test Procedure: Moncla Rig 404, WO Program — Oil Producers, Water Injectors Pre Rig Move 1) Blow down well, bleed gas to Well Clean Tank that is vented thru flare to atmosphere 2) Load well with FIW to kill well. • Note: Fluid level will fall to a depth that balances with reservoir pressure. 3) Shoot fluid level at least 24 hours before moving on well. 4) Shoot fluid level again, right before ND/NU. Confirm that well is static. Initial Test(i.e.Tubing Hanger is in the Wellhead) If BPV profile is good 1) Set BPV. ND Tree. NU BOP. 2) MU landing joint. Pull BPV. Set 2-way check in hanger. 3) Space out test joint so end of tubing(EOT)is just above the blind rams. 4) Set slips, mark same. Test BOPE per standard test procedure. If the tubing hanger won't pressure test due to either a penetrator leak or the BPV profile is eroded and/or corroded and BPV cannot be set with tree on.Profile and/or landing threads must be prepped while tree is off.Worst Case: BPV profile and landing threads are bad. 1) Attempt to set BPV through tree. If unsuccessful,shoot fluid level. 2) If fluid level is static from previous fluid level shots, notify Hilcorp Anchorage office that the well is static and the tree must be removed with no BPV.As approved in the sundry, proceed as follows: a) ND tree with no BPV b) Inspect and prepare BPV profile to accept a 2-way valve,or prepare lift-threads to accept landing joint to hold pressure. If well is a producer and the culprit is scale,attempt to clean profile with Muriatic acid and a wire brush or wheel. c) Set 2-way check valve by hand,or MU landing(test)joint to lift-threads d) For ESP wells-Ensure that cap is on cable penetrator e) NU BOP. Test BOPE per standard procedure. 3) If both set of threads appear to be bad and unable to hold a pressure test and/or a penetrator leaks, notify Operations Engineer(Hilcorp), Mr.Guy Schwartz(AOGCC)and Mr.Jim Regg(AOGCC)via email explaining the wellhead situation prior to performing the rolling test. AOGCC may elect to send an inspector to witness. As outlined and approved in the sundry, proceed as follows: a) Nipple Up BOPE b) With stack out of the test path,test choke manifold per standard procedure c) Conduct a rolling test: Test the rams and annular with the pump continuing to pump, (monitor the surface equipment for leaks to ensure that the fluid is going down-hole and not leaking anywhere at surface.) d) Hold a constant pressure on the equipment and monitor the fluid/pump rate into the well. Record the pumping rate and pressure. e) Once the BOP ram and annular tests are completed,test the remainder of the system following the normal test procedure(floor valves,gas detection,etc.) • • Moncla Rig 404 BOP Test Procedure Hilrarp Alaska,IAA, Attachment#1 f) Record and report this test with notes in the remarks column that the tubing hanger/BPV profile/ penetrator wouldn't hold pressure and rolling test was performed on BOP Equipment and list items, pressures and rates. 4) Pull hanger to surface. (Requires tubing cuts as necessary to free tubing). CBU to displace annulus and tubing with kill weight fluid. 5) If a rolling test was conducted, remove the old hanger, MU new hanger or test plug to the completion tubing. Re-land hanger(or test plug)in tubing head. Test BOPE per standard procedure. Subsequent Tests(i.e.Test Plug can be set in the Tubing-head) 1) Remove wear bushing. a) Use inverted test plug to pull wear busing. MU to joint of tubing. b) Thread into wear bushing c) Back out hold down pins d) Pull and retrieve wear bushing. 2) Break off test plug and invert same-RIH with test plug on joint of tubing. Install a pump-in sub w/test line plus an open TIW or lower Kelly valve in top of test joint w/open IBOP. 3) Test BOPE per standard procedure. STANDARD BOPE TEST PROCEDURE(after 2-way check or test plug is set) 1) Fill stack and all lines with rig pump-install chart recorder on test line connected to pump-in sub below safety valve and IBOP in test joint assembly. 2) Note: When testing, pressure up with pump to desired pressure,close valve on pump manifold to trap pressure and read same with chart recorder(test pressures will be indicated in Sundry). 3) Referencing the attached schematics test rams and valves as follows. a) Close 1st valve on standpipe manifold,close valves 1,2, 10 on choke manifold and close the annular preventer,open safety valve on top of test jt and close IBOP. Pressure test to 250 psi for 5 minutes and 2,500 psi high for 5 minutes. If passes after 5 minutes on each, bleed off pressure back to tank and open annular. b) Close pipe rams and open annular preventer,close safety valve and open IBOP on test joint, close outside valve on kill side of mud cross,open 1St valve of standpipe,close valves 3,4&9 on choke manifold,open valves 1&2 on choke manifold. Test to 250 psi for 5 minutes and 3,000 psi high for 5 minutes. If passes after 5 minutes on each, bleed off pressure back to tank. c) Test Dual Rams. If the well has dual tubing,and dual rams are installed in the stack,test the dual rams by picking up two test joints with dual elevators and lowering them into stack and position them properly in the dual rams. Close rams. Test to 250 psi for 5 minutes and 3,000 psi for 5 minutes. If passes after 5 minutes on each, bleed off pressure back to tank. d) Close inside valve/open outside valve on kill side of mud cross,close valves 5&6/open valves 3&4 on choke manifold. Test to 250 psi for 5 minutes and 3,000 psi for 5 minutes. If passes after 5 minutes on each,bleed off pressure back to tank. e) Close manual and super choke/open valves 5&6 on choke manifold. Pressure up to^ 1200 psi and bleed off 200—300#s recording change and stabilization. If passes after 5 minutes, bleed of pressure back to tank. f) Close HCR(outside valve on choke side of mud cross),open manual&super choke. Test to 250 psi for 5 minutes and 3000 psi for 5 minutes. If passes after 5 minutes on each, bleed off pressure back to tank. Moncla Rig 404 BOP Test Procedure 4110 • Hilrorp.Alaeka, Attachment#1 g) Close inside valve/open outside valve(HCR)on choke side of mud cross. Test to 250 psi for 5 minutes and 3000 psi for 5 minutes. If passes after 5 minutes on each, bleed off pressure back to tank. h) Ensure all pressure is bled off-open pipe rams and pull test joint leaving test plug/2-way check in place. Close blind rams and attach test line to valve 10 on choke manifold,close valve 7&8/open valve 10 on choke manifold. Test to 250 psi for 5 minutes and 3000 psi for 5 minutes. If passes after 5 minutes on each, bleed off pressure back to tank. i) Test additional floor valves(TIW or Lower Kelly Valve)and IBOPs as necessary. STANDARD TEST PROCEDURE OF CLOSING UNIT(ACCUMULATOR) 1) This is a test of stored energy. Shut off all power to electric and pneumatic pumps. 2) Record "Accumulator Pressure". It should be+/-3,000 psi. 3) Close Annular Preventer,the Pipe Rams,and HCR. Close 2nd set of pipe rams if installed(e.g.dual pipe rams). Open the lower pipe rams to simulate the closing volume on the blinds. 4) Allow pressures to stabilize. 5) While stabilizing: Record pressure values of each Nitrogen bottle and average over the number of bottles. (i.e. Report might read "10 bottles at 2,150 psi"). 6) After accumulator has stabilized, record accumulator pressure again. This represents the pressure and volume remaining after all preventers are closed. (The stabilized pressure must be at least 200 psi above the pre- charge pressure of 1,000 psi). 7) Turn on the pump and record the amount of time it takes to build an additional 200 psi on the accumulator gauge. This is usually+/-30 seconds. 8) Once 200 psi pressure build is reached,turn on the pneumatic pumps and record the time it takes for the pumps to automatically shut-off after the pressure to builds back to original pressure(+/-3,000 psi). Note: Make sure the electric pump is turned to"Auto", not"Manual"so the pumps will kick-off automatically. 9) Open all rams and annular and close HCR to place BOPE back into operating position for well work. 10) Fill out AOGCC report. FINAL STEP,FINAL CHECK 1) Test Gas Alarms 2) Double check all rams and valves,for correct operating position 3) Fill out the AOGCC BOPE Test Form(10-424)in Excel Format and e-mail to AOGCC and Juanita Lovett. Document both the rolling test and the follow up tests. r 0 • c2 � 2 � � 0 a) k � 2 0 co a e $ E 0 o § � 0 2k3. gw � a E ® CD O . 2 = § 10. >..-03 R < a. 3 ».- 7 / )U) U) m w Y \ = f 2 .E �.§ CL _ CO .L n -0 ■ a) Fl_ o er � 2 9 $ / a) O o k co ZJ O k / @ a % i 13 ui - > @ o Q4 2 E N CD k § ■ ƒ _ »e — .0 c O k / % a) i) k 03) 2 E § © 2 O k S .$ a § / a. = co \/ g a) »7 § c § 2 / E . Cl) 2p 2 % 2 0 2 @ 2 § W a o 0 a E � CI 0 . Q g > o ■ - Q 03o § O ° & ® X. o / a. � ' CLI V) S % £ U) U .. 2 = . . ° k a 2 00 U C Q ƒ e ® 2 0 ° 2 E 2 2 k / < & STATE OF ALASKA AL&OIL AND GAS CONSERVATION COM ION REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon 0 Plug Perforations❑ Fracture Stimulate ❑ Pull Tubing❑ Operations shutdown ❑ Performed: Suspend 0 Perforate 0 Other Stimulate ❑ Alter Casing❑ Change Approved Program ❑ Plug for Redrill 0 Perforate New Pool 0 Repair Well 0 Re-enter Susp Well El Other: 0 2.Operator 4.Well Class Before Work: 5.Permit to Drill Number: Name: Hilcorp Alaska,LLC Development 0 Exploratory 0 195-012 3.Address: 3800 Centerpoint Drive,Suite 1400 Stratigraphic❑ Service ❑ 6.API Number: Anchorage,AK 99503 50-733-20258-01 7.Property Designation(Lease Number): 8.Well Name and Number: :T .,�.. h " maw. ADL0018754 MGS A24-01 LE 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): A LI(; 15 2816 N/A Middle Ground Shoal/E,F and G Oil Pools 11.Present Well Condition Summary: °°� r GC Total Depth measured 11,994 feet Plugs measured N/A feet true vertical 9,827 feet Junk measured N/A feet Effective Depth measured 11,941 feet Packer measured 9,824 feet true vertical 9,815 feet true vertical 8,572 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 370' 24" 370' 370' Surface 2,010' 13-3/8" 2,010' 1,830' 3,090 psi 1,540 psi Intermediate Production 10,013' 7" 10,013' 8,731' 8,160 psi 7,020 psi Liner 2,811' 5" 11,994' 9,805' 10,140 psi 10,490 psi Perforation depth Measured depth 9,965-11,784 feet True Vertical depth 8,690-9,780 feet 2-7/8" 6.5#/L-80 9,144'(MD) 8,014'(ND) Tubing(size,grade,measured and true vertical depth) 2-3/8" 4.7#/N-80 9,902'(MD) 8,637'(ND) 9,824'(MD) 311'(MD) Packers and SSSV(type,measured and true vertical depth) Baker FH Packer 8,572'(ND) Baker FV-6 TRSCSSV 311'(ND) 12.Stimulation or cement squeeze summary: Intervals treated(measured): SCANNED �y N/A NNED JAlY 20i7 Treatment descriptions including volumes used and final pressure: N/A 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 7 7 38 759 79 Subsequent to operation: 18 17 55 734 79 14.Attachments(required per 20 AAC 25.070,25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations ❑ Exploratory❑ Development❑ Service❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16.Well Status after work: Oil ❑. Gas ❑ WDSPL❑ Printed and Electronic Fracture Stimulation Data ❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ 0 SUSP❑ SPLUG❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: 316-326 Contact Dan Marlowe(907)283-1329 Email dmarlowecc hilcorp.com Printed Name Stan W.Golis Title Operations Manager Signature Ck Phone (907)777-8356 Date $ f 1 is/itt Form 10-404 Revised 5/2015 RBDMS t-A--A113 1 5 2016 Submit Original Only 11110 . Middle Ground Shoal Well:MGS A24-01LE , H SCHEMATIC Last Completed: 5/10/95 PTD: 195-012 Hik ora Alaska,LLC API: 50-733-20258-01 RKB:MSL=96' CASING DETAIL s1 S.44.11 ize Wt Grade Conn ID Top Btm to'lli 24" Surf 370' 24 ii 13-3013 3/8" 61 K-55 BTC 12.515 Surf 2,010' 7" 29 N-80 BTC 6.184 Surf10,013' (KO P) r5" 18 L-80/P-110 STL 4.276 9,170' 11,994' TUBING DETAIL 11 2-7/8" 6.5 L-80 8rd 2.441 Surf 9,144' 2-3/8" 4.7 N-80 8rd 1.995 9,144' 9,902' 0 JEWELRY DETAIL Depth Depth 0 No ID Item (MD) (TVD) 311' 311' 2.31 Baker FV-6 TRSCSSV 0 2,095' 1,904' 2.441 GLM#1 3,789' 3,390' 2.441 GLM#2 a 5,132' 4,548' 2.441 GLM#3 6,158' 5,397' 2.441 GLM#4 Iti 6,867' 5,998' 2.441 GLM#5 7,448' 6,510' 2.441 GLM#6 Top of liner -- .tim 7,998' 7,005' 2.441 GLM#7 @9,17Y 8,544' 7,502' 2.441 GLM#8 9,097' 7,977' 2.441 GLM#9 9,144' 8,014' 1.995 X-Over 2-7/8"to 2-3/8" 9,744' 8,505' 1.995 GLM#10 '''A"(16)Orifice Valve 9,791' 8,544' 1.875 X Nipple XN 9,824' 8,572' Baker"FH"Packer 9,869' 8,609' 1.791 XN Nipple 4 k 9,902' 8,637' Modified Wireline Re-entry Guide 7, PERFORATION DETAIL = Zone Top(MD) Btm(MD) Top(ND) (Np) FT Date Status 7/19/16- =2 9,965' 10,025' 8,690' 8,742' 60 7/20/16 Open H2 10,048' 10,073' 8,761' 8,783' 25' 3/11/2016 Open H2 10,075' 10,095' 8,785' 8,802' 20' 3/10/2016 Open H2 10,135' 10,145' 8,836' 8,845' 10' 7/20/16 Open H1-H2 10,200' 10,242' 8,892' 8,929' 42' H2 10,330' 10,406' 9,006' 9,073' 76' - H2 10,426' 10,686' 9,090' 9,313' 260' H2 10,790' 10,918' 9,396' 9,485' 128' H2 11,016' 11,187' 9,539' 9,611' 171' - H2 11,358' 11,548' 9,672' 9,725' 190' H1-H2 11,564' 11,610' 9,729' 9,741' 46' H1 11,682' 11,713' 9,757' 9,764' 31' 5 H1 11,736' 11,784' 9,769' 9,780' 48' PBTD:11,941' TD:11,994' Updated By:JLL 08/11/16 • r Hilcorp Alaska, LLC HilcorpAlaska,LLC Well Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date MGS A-24-01LE E-Line 50-733-20258-01 195-012 7/19/2016 7/20/2016 7/19/16-Tuesday Safety meeting and permit.ELU PT=250/3500.Pickup Perf Gun#1,10'of 1-9/16"GeoDynamics Razor(6 spf,60 deg.phase)with GR/CCL source to Top Shot=3.80'.Rig to WHA,open swab valve and RIH.Initial T/IA/OA=68/382/28.RIH w/Gun#1 to 10,200'.PUH logging 10,200'-9950'to correlate depth. Depth correct and repeat logging pass 10,200'-9950'.Send LAS file for depth verification and return to 10,200'.Depth verification received.PUH to 10,131.2'(+3.80'=10,135'Top Shot)to place shots on depth.Fire guns,good surface indication of shots fired=10,135'-10,145'.POOH;@ surface with shots fired.LD Gun#1&PU Gun#2.T/IA/OA=68/382/28.RIH w/Gun#2,20'of 1-9/16"GeoDynamics Razor(6spf,60 deg.phase)with GR/CCL source to Top Shot=4.20'.10,100'-9950',log up to correlate depths.Correct depth and repeat 10,100'-9950'logging pass.Return to 10,100'and PUH to place shots on depth=10,000.8'(+4.20'=10,005.0'Top Shot).Fire guns,good surface indication of shots fired=10,005'-10,025'.POOH;@ surface with shots fired.Final T/IA/OA=68/382/28.Rig off WH.LD Gun#2.Secure Well&Well Room#4.Lay Down ELU.Shut down for night. 7/20/16-Wednesday Safety meeting and permit.PT ELU=250/3500.PU Gun#3,20'X 1-9/16"GeoDynamic Razor(6spf,60 deg.phase).GR/CCL source to Top Shot=3.90'. Initial T/IA/OA=300/384/27.RIH to 10,020'.Log up to correct depth.TIH to 10,150'.Log 10,150-9,950'to confirm depth correlation;return to 10,150'. PUH to place shots on depth=9,981.1'GR/CCL source depth(+3.90'=9,985'Top Shot).Fire Gun#3 perforating 9,985'-10,005'(6spf,60 deg).POOH. T/IA/OA=360/384/27.Return to surface with Gun#3 shots fired.Lay down Gun#3&PU Gun#4,20'x 1-9/16"GeoDynamic Razor(6spf,60 deg).GR/CCL source to Top Shot=4.20'.RIH to 10,020'.Log up to correct depth.TIH to 10,100',Logging pass 10,100'-9,900'to confirm depth correlation;return to 10,100'.PUH to place shots on depth =9,960.8'GR/CCL source depth(+4.20'=9,965'Top Shot).Fire Gun#4 perforating 9,965'-9,985'(6spf.60 deg). POOH,Return to surface with Gun#4,shots fired.Rig Down ELU.Turnover well to Production Operator.Job Ended.Final T/IA/OA=450/384/27. • • tioF rit k. THE STATE Alaska Oil and Gas ti .r�!•''�� f A T A 1�/C�lsJL`� Conservation Commission O 1 1L1 l 1 13i1 _ 333 West Seventh Avenue 'fir GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279.1433 OF ALAS Fax: 907.276.7542 www.aogcc.alaska.gov Stan W. Golis Operations Manager SCANNED JAN 0 9 2..017, Hilcorp Alaska, LLC 3800 Centerpoint Dr., Ste. 1400 Anchorage,AK 99503 Re: Middle Ground Shoal Field, E, F,and G Oil Pools, MGS A24-01 LE Permit to Drill Number: 195-012 Sundry Number: 316-326 Dear Mr. Golis: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, _i-t a;4ee4k Cathy P. Foerster Chair DATED this eilay of June, 2016. RBDMS Gv JUN 1 3 2016 • • RECEIVED STATE OF ALASKA JUN 0 8 2016 ALASKA OIL AND GAS CONSERVATION COMMISSION ars V t,16, APPLICATION FOR SUNDRY APPROVALS AOGCC 20 AAC 25.280 1.Type of Request: Abandon ❑ Plug Perforations❑ Fracture Stimulate ❑ Repair Well ❑ Operations shutdown Suspend ❑ Perforate 9 Other Stimulate 0 Pull Tubing ❑ Change Approved Program❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other. ❑ 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number. Hilcorp Alaska,LLC • Exploratory ❑ Development 9- 195-012 • 3.Address: 3800 Centerpoint Drive,Suite 1400Stratigraphic ❑ Service ❑ 6.API Number. Anchorage,AK 99503 50-733-20258-01 ' 7.If perforating: 8.Well Name and Number. What Regulation or Conservation Order governs well spacing in this pool? CO 44 Will planned perforations require a spacing exception? Yes 0 No CI MGS A24-01 LE ' 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL0018754 Middle Ground Shoal/E,F and G Oil Pools 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP(psi): Plugs(MD): Junk(MD): 11,994 . 9,827 - 11,941 . 9,815 —100 psi N/A N/A Casing Length Size MD TVD Burst Collapse Structural Conductor 370' 24" 370' 370' Surface 2,010' 13-3/8" 2,010' 1,830' 3,090 psi 1,540 psi Intermediate Production 10,013' 7" 10,013' 8,731' 8,160 psi 7,020 psi Liner 2,811' 5" 11,994' 9,805' 10,140 psi 10,490 psi Perforation Depth MD(ft): Perforation Depth ND(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 10,048-11,784 • 8,761 -9,780 2-7/8"&2-3/8" 6.5#/L-80&4.7#N/L-80 9,144&9,902 Packers and SSSV Type: Packers and SSSV MD(ft)and ND(ft): Baker FH Packer&Baker FV-6 TRSCSSV ' 9,824'(MD)8,572'(TVD) &311'(MD)311'(TVD) 12.Attachments: Proposal Summary 9 Wellbore schematic 9 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic❑ Development 0 ' Service ❑ 14.Estimated Date for 15.Well Status after proposed work: 6/23/2016 Commencing Operations: OIL 0- WINJ ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Contact Dan Marlowe(907)283-1329 Email dmarlowe©hilcorp.com Printed Name Stan W.Golis _ t Title Operations Manager ) Signature ` Q L,3 `U --- Phone (907)777-8356 Date 6 I -7 t COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: \Le, _'' �� Plug Integrity ❑ BOP Test❑ Mechanical Integrity Test ❑ Location Clearance ❑ • Other: Post Initial Injection MIT Req'd? Yes ❑ No ❑ RBDMS 1,1/ JUN 1 3 2016 Spacing Exception Required? Yes ❑ No Subsequent Form Required: 10- ‘10,1 APPROVED BY Approved by:A��aa99,...(A,I>itt COMMISSIONER THE COMMISSION Date:��e4 - G l i. 01,R$G4NAL -��.4... 6 `7-/.4 Submit Form and Form 10-403 Revised 11/2015 for 12 months 1i6m the date of pproval. Attachments in Duplicate . • Well Prognosis Well: MGS A24-01LE HBenrp Date: 06/07/2016 Well Name: MGS A24-01LE API Number: 50-733-20258-01 Current Status: Gas-Lifted producer Leg: Leg#4 South corner Estimated Start Date: June 23, 2016 Rig: N/A (E-Line) Reg.Approval Req'd? 403 Date Reg. Approval Rec'vd: Regulatory Contact: Juanita Lovett (8332) Permit to Drill Number: 195-012 First Call Engineer: Dan Marlowe (907) 283-1329 (0) (907) 398-9904 (M) Second Call Engineer: Trudi Hallett (907) 777-8323 (0) (907) 301-6657 (M) Current Bottom Hole Pressure: 2,538 psi @ 8,000'TVD 0.330 psi/ft datum 2016 PBU Maximum Expected BHP: 4,000 psi @ 8,000'TVD 0.490 psi/ft datum upper zone/offsets Maximum Potential Surface Pressure: -100 psi Well to be perforated while flowing Brief Well Summary Well Middle Ground Shoal A24-01LE is a gas-lifted oil well completed in the Hemlock zone.This project will add Hemlock sands not currently perforated. / E-line Procedure: 1. MIRU E-line, PT lubricator to 3,500 psi Hi 250 Low. 2. RU e-line guns and perforate per program. Record tubing pressures before and after perforating run. 3. RD E-line. 4. Turn well over to production. Attachments: 1. Current Wellbore Schematic 2. Proposed Wellbore Schematic • Middle Ground Shoal • Well: MGS A24 01LE 0 nSCHEMATIC d: 5/10/95 PTD: 195-012 na,•,„ri, 113.1..a.1.1.1 API: 50-733-20258-01 RKB:MSL=96' CASING DETAIL J1r L Size Wt Grade Conn ID Top Bt:'.2Q` 24" Surf 370' 13-3/8" 61 K-55 BTC 12.515 Surf 2,010' @ 7" 29 N-80 BTC 6.184 Surf 10,013' 13-3Ar (KOP) 5" 18 L-80/P-110 STL 4.276 9,170' 11,994' TUBING DETAIL N 2-7/8" 6.5 L-80 8rd 2.441 Surf 9,144' 2-3/8" 4.7 N-80 8rd 1.995 9,144' 9,902' @ JEWELRY DETAIL Depth Depth No ID (MD) ;Tv Di 311' 311' 2.31 Baker FV-6 TRSCSSV 0 2,095' 1,904' 2.441 GLM#1 3,789' 3,390' 2.441 GLM#2 @ 5,132' 4,548' 2.441 GLM#3 6,158' 5,397' 2.441 GLM#4 6,867' 5,998' 2.441 GLM#5 0 7,448' 6,510' 2.441 GLM#6 Top of liner 7,998' 7,005' 2.441 GLM#7 @ 9,170` 8,544' 7,502' 2.441 GLM#8 0 9,097' 7,977' 2.441 GLM#9 9,144' 8,014' 1.995 X-Over 2-7/8"to 2-3/8" mi„X on 9,744' 8,505' 1.995 GLM#10 'A"(16)Orifice Valve 9,791' 8,544' 1.875 X Nipple N ED 9,824' 8,572' Baker"FH"Packer 9,869' 8,609' 1.791 XN Nipple 4 i 9,902' 8,637' Modified Wireline Re-entry Guide r PERFORATION DETAIL Btm Zone Top(MD) Btm(MD) Top(TVD) (TVD) FT Date Stag-„ H2 10,048' 10,073' 8,761' 8,783' 25' 3/11/2016 Open H2 10,075' 10,095' 8,785' 8,802' 20' 3/10/2016 Open H1-H2 10,200' 10,242' 8,892' 8,929' 42' H2 10,330' 10,406' 9,006' 9,073' 76' H2 10,426' 10,686' 9,090' 9,313' 260' H2 10,790' 10,918' 9,396' 9,485' 128' H2 11,016' 11,187' 9,539' 9,611' 171' H2 11,358' 11,548' 9,672' 9,725' 190' H1-H2 11,564' 11,610' 9,729' 9,741' 46' H1 11,682' 11,713' 9,757' 9,764' 31' H1 11,736' 11,784' 9,769' 9,780' 48' 5' 4 .* PBTD:11,941' ID:11,994' Updated By:.ILL 06/07/16 H • Middle Ground Shoal III Well:MGS A24-01LE SCHEMATIC Last Completed: 5/10/95 PTD: 195-012 Hilcorp Alaska,LLC API: 50-733-20258-01 RKB:MSL=96' CASING DETAIL i , ' Size Wt Grade Conn ID Top Btm ," ' a 24" Surf 370' 24" 13-3/8" 61 . K-55 BTC 12.515 Surf 2,010' 4 7" '29 N-80 BTC 6. .4 Surf 10,013' 13-3/8 (KOP) w ` - 5" 18 L-80 STL 4.276 9,183' ii 5" 18 P110 STL 4.276 11,994' TUBI DETAIL 2-7/8" 6.5 L-80 ' d 2.441 Surf 9,144' 6 2-3/8" 4.7 N-80 8rd 1.995 9,144' 9,902' 6 JEWELRY DETAIL h1 No Depth Depth ID Item (MD) (TV► 311' 31 ' 2.31 Baker FV-6 TRSCSSV 0 2,095' '04' 2.441 GLM#1 3,789' ,390' 2.441 GLM#2 6 5,132' 4,548' 2.441 GLM#3 6,15' 5,397' 2.441 GLM#4 6,'.7' 5,998' 2.441 GLM#5 0 ,448' 6,510' 2.441 GLM#6 7,998' 7,005' 2.441 GLM#7 8,544' 7,502' 2.441 GLM#8 9,097' 7,977' 2.441 GLM#9 11 9,144' 8,014' 1.995 X-Over 2-7/8"to 2-3/8" Li 9,744' 8,505' 1.995 GLM#10 '''A"(16)Orifice Valve II9,791' 8,544' 1.875 X Nipple • . 9,824' 8,572' Baker"FH"Packer j[ WA 1" e 9,869' 8,609' 1.791 XN Nipple 1 -1 )DOl,3' 9,902' 8,637' Modified Wireline Re-entry Guide r = . , PERFORATiO I DETAIL Zone Top(MD) , tBta.m(MD) To (TVD) (¢ . Bt� f t FT Date Status _w. a [ l H2 10,048' 10,073'' , 1' • -8,783' 25' 3/11/2016 Open H2 10,075' 10,095' 8,785' 8,802' 20' 3/10/2016 Open H1-H2 10,200' 10,242' 8,892' 8,929' 42' - H2 10,330' 10,406' 9,006' 9,073' 76' H2 10,426' 10,686' 9,090' 9,313' 260' H2 10,790' 10,918' 9,396' 9,485' 128' H2 11,016' 11,187' 9,539' 9,611' 171' H2 11,358' 11,548' 9,672' 9,725' 190' H1-H2 11,564' 11,610' 9,729' 9,741' 46' H1 11,682' 11,713' 9,757' 9,764' 31' H1 11,736' 11,784' 9,769' 9,780' 48' 5441111M) MD:11,941' TD:11,994' Updated By:.ILL 06/07/16 • MiddGho Well:le MGS A24round S01LEal PROPOSED Last Completed: 5/10/95 PTD: 195-012 Hilcorp Alaska,LLC API: 50-733-20258-01 RKB:MSL=96' CASING DETAIL Size Wt Grade Conn ID Top Btm 24 124" Surf 370' 13-3/8" 61 K-55 BTC 12.515 Surf 2,010' 1 10,013' 7" 29 N-80 BTC 6.184 Surf (KOP) 13-3/8” 5" 18 L-80 STL 4.276 9,183' II i 5" 18 P110 STL 4.276 11,994' TUBING DETAIL II2-7/8" 6.5 L-80 8rd 2.441 _ Surf 9,144' Mt i 2-3/8" 4.7 N-80 8rd 1.995 9,144' 9,902' i MI i 111 JEWELRY DETAIL J i No Depth Depth ID Item (MD) (ND) 311' 311' 2.31 Baker FV-6 TRSCSSV 1 i 2,095' 1,904' 2.441 GLM#1 3,789' 3,390' 2.441 GLM#2 Ili i 5,132' 4,548' 2.441 GLM#3 6,158' 5,397' 2.441 GLM#4 6,867' 5,998' 2.441 GLM#5 V i 7,448' 6,510' 2.441 GLM#6 7,998' 7,005' 2.441 GLM#7 >s 8,544' 7,502' 2.441 GLM#8 I!i 9,097' 7,977' 2.441 GLM#9 110 ,t---", �t 9,744' 8,505' 1.995 GLM#10 '''/"(16)Orifice Valve ,' 111 )11 9,791' 8,544' 1.875 X Nipple 51-1 9,824' 8,572' Baker"FH"Packer r 9,869' 8,609' _ 1.791 XN Nipple 4` 4, 1� 9,902' 8,637' Modified Wireline Re-entry Guide 7' PERFORATION DETAIL Zone Top(MD) Btm(MD) Top(ND) (Np) FT Date Status J H2 ±9,965' ±10,025' ±8,690' ±8,742' ±60 Future H2 10,048' 10,073' 8,761' 8,783' 25' 3/11/2016 Open H2 10,075' 10,095' 8,785' 8,802' 20' 3/10/2016 Open H2 ±10,135' ±10,145' ±8,836' ±8,845' ±10' Future = H1-H2 10,200' 10,242' 8,892' 8,929' 42' H2 10,330' 10,406' 9,006' 9,073' 76' H2 10,426' 10,686' 9,090' 9,313' 260' H2 10,790' 10,918' 9,396' 9,485' 128' H2 11,016' 11,187' 9,539' 9,611' 171' H2 11,358' 11,548' 9,672' 9,725' 190' - H1-H2 11,564' 11,610' 9,729' 9,741' 46' H1 11,682' 11,713' 9,757' 9,764' 31' 5" 44ia6 H1 11,736' 11,784' 9,769' 9,780' 48' PBTD:11,941' TD:11,994' Updated By:JLL 06/07/16 • • Schwartz, Guy L (DOA) From: Dan Marlowe <dmarlowe@hilcorp.com> Sent: Thursday,June 09, 2016 9:44 AM To: Schwartz,Guy L(DOA) Cc: Bettis, Patricia K(DOA);Juanita Lovett Subject: RE: MGS A24-01LE perfs(PTD 195-012) Attachments: A24-01LE Schematic 2016-06-09.pdf;Casing Tally 5.0001995-04-21 and cement details.pdf Follow Up Flag: Follow up Flag Status: Flagged Sir I see your concern and unfortunately our schematic added confusion to the issue Please reference revised schematic as the one submitted was incorrect.The casing detail was close but misleading and the drawing was not accurate as the 5" doesn't come to surface. I was able to locate and tighten up the casing details to correctly pinpoint top of the tie back sleeve. (The original top of 5" only referenced pipe top ignoring jewelry) Cement top- It doesn't appear that XTO ran a CBL on the 5" casing string ran during the side-track operation in 1995. I did find that on 4/22/95 they pumped 448 sx, bumped the plug and the floats held. During the cleanout they tagged cement at 7315' which is 1855'above liner top so looks like they did indeed get returns well above top of liner.After cleaning out they tested the liner top on 4/23/95 to 1500 psi. (Details attached) I apologize for the confusion Dan Marlowe Hilcorp Alaska, LLC Operations Engineer Office 907-283-1329 Cell 907-398-9904 Fax 907-283-1315 Email DMarlowe anhilcorp.com Hilcorp A Company Built on Energy From: Schwartz, Guy L(DOA) [mailto:guy.schwartz@alaska.gov] Sent: June 08, 2016 3:58 PM To: Dan Marlowe Cc: Bettis, Patricia K(DOA) Subject: MGS A24-01LE perfs(PTD 195-012) Dan, 1 • .Can you clarify where Top of cemen is in the 5"casing? Also noticed you have a 1.79" ID restriction that will severely limit your perf gun choices. Will be difficult to penetrate both 5" and 7"on the upper zone and still contact reservoir. Guy Schwartz Sr. Petroleum Engineer AOGCC 907-301-4533 cell 907-793-1226 office CONFIDENTIALITY NOTICE:This e-mail message,including any attachments,contains information from the Alaska Oil and Gas Conservation Commission (AOGCC),State of Alaska and is for the sole use of the intended recipient(s).It may contain confidential and/or privileged information.The unauthorized review,use or disclosure of such information may violate state or federal law.If you are an unintended recipient of this e-mail,please delete it,without first saving or forwarding it,and,so that the AOGCC is aware of the mistake in sending it to you,contact Guy Schwartz at(907-793-1226) or(Guy.schwartz@alaska.gov). 2 ._ • • SWEPI KA DAILY DRILLING REPORT PAGE 1 OF 1 R."- NAME PLATFORM 'A' PROD. DEPTH 11943 ELEVAT. KB TO MSL 116.0 DATE 04/23/95 . ) MIDDLE GROUND SHOAL PRESENT DEPTH 11994 DIST. KB TO BHF 38.4 DAY 32 LEASE PLATFORM 'A' FOOTAGE DRILLED NLTA LTH/YTD _/_ EST. DAY 22 WELL A24-01LE SIZE OF LAST CSG 7.000 LTA LTH/YTD _/_ DAYS +/- WORK ORDER 723530 DEP. OF LAST CSG 10013 DAYS SINCE LAST LTA 748 SIDE TRACK WATER DEPTH 80 LAST BOP TEST 04/14/95 LAST CSG TEST 03/26/95 DRILLING FOREMAN: WELLS R V /FREDERICK DA BHA INSPECTION (CUM. ROT HRS) PRESENT ACTIVITY: PUMPING DRY JOB PP1 47 KILL SPEED 2850 ® 30 PP2 W KILL SPEED _ 47 SO SUMMARY OF OPERATIONS (SHOW HOURS FOR EACH OPERATION) 4.50 DRILL CEMENT FROM 8760' TO 9168' (TOL) TIME (HRS) 1.50 CIRCULATE BOTTOMS UP % 9168' - PRESSURE TEST LINER TOP AND 7' CASING CUM. ROT. HAS 270.50 TO 1500# FOR 10 MIN. - HELD OK ROTATING 7.50 2.50 POOH WITH CLEAN OUT ASSY AND BIT #4RR MUD MOTOR 1.50 LAY DOWN BHA - RIG UP 2-7/8' EQUIPMENT - MAKE UP 4-1/8" MILL AND TRIPPING 8.50 3-1/8' DC'S C & C 5.50 4.50 RIM WITH 2-7/8" AND 3-1/2' DP TO TOL REAMING 1.00 BREAK CIRCULATION - DRILL CEMENT FROM 9168' TO 9175' SURVEYS 3.50 RIH - CLEAN OUT CEMENT STRINGERS - TAG CEMENT 43 11752' - DRILL TO JET 11941' (TOP OF LANDING COLLAR) REPAIRS 2.50 CIRCULATE BOTTOMS UP ® 11941' FISHING .50 PRESSURE TEST 5' LINER TO 1500# FOR 10 MIN. - HELD OK NIP UP/DOWN /BOP/WH ! 2.00 CIRCULATE AND CONDITION MUD - PUMP DRY JOB TESTING BOP /WH RUNNING CASING CEMENTING PICKUP/LAY DOWN DS .50 INSPECT BHA RIG UP/TEAR DOWN WAIT ON WEATHER/MAT EVALUATION CORING OTHERS 2.00 SWEPI ALASKA DAILY DRILLING REPORT PAGE 1 OF 1 RT^- NAME PLATFORM 'A' PROD. DEPTH 11943 ELEVAT. KB TO MSL 116.0 DATE 04/24/95 D MIDDLE GROUND SHOAL PRESENT DEPTH 11994 DIST. KB TO BHF 38.4 DAY 33 LLASE PLATFORM "A' FOOTAGE DRILLED NLTA LTH/YTD / EST. DAY 22 WELL A24-01LE SIZE OF LAST CSG 5.000 LTA LTH/YTD _/_ DAYS +/- WORK ORDER 723530 DEP. OF LAST CSG 11994 DAYS SINCE LAST LTA 749 SIDE TRACK _ WATER DEPTH 80 LAST BOP TEST 04/14/95 LAST CSG TEST 03/26/95 DRILLING FOREMAN: WELLS R V /FREDERICK DA BHA INSPECTION (CUM. ROT HRS) PRESENT ACTIVITY: TEST CASING PP1 @ KILL SPEED 2850 B 30 PP2 ® KILL SPEED ® 50 SUMMARY OF OPERATIONS (SHOW HOURS FOR EACH OPERATION) : 2.00 POOH WITH CLEAN OUT ASSY SLOW (WET) TIME (HRS) 1.00 MIX AND PUMP DRY JOB CUM. ROT. HRS 270.50 4.00 POOH (WET) - LAY DOWN 4-1/8" MILL ROTATING 1.50 MAKE UP 5" SCRAPER - RIH WITH 2-7/8" DP MUD MOTOR 3.50 MAKE UP 7" SCRAPER - RIM WITH 3-1/2" DP (TANDEM ASSY) TRIPPING 11.00 6.00 TAG LANDING COLLAR & 11941' - CIRCULATE AND CONDITION MUD - RUN C & C 12.50 CENTRIFUGE - WORK AND ROTATE PIPE REAMING 5.50 REVERSE CIRCULATE OBM OUT OF WELLBORE - DISPLACE WITH FIW - PUMP 20 SURVEYS BBL XANVIS SWEEP FOLLOWED WITH FIW - TRANSFER 525 BELS 11.8 PPG OBM JET RETURNS TO STORAGE TANK - FLUSH FLOWLINE AND CHOKE MANIFOLD REPAIRS .50 POOH 10 STD DP - RIG UP TO TEST CASING . FISHING NIP UP/DOWN /BOP/WH TESTING BOP /WH RUNNING CASING CEMENTING PICKUP/LAY DOWN DS .50 INSPECT BHA RIG UP/TEAR DOWN WAIT ON WEATHER/MAT EVALUATION CORING 0,--, • ♦ SWEPI KA DAILY DRILLING REPORT PAGE 1 OF 1 RIC. NAME PLATFORM 'A' PROG. DEPTH 11943 ELEVAT. KB TO MSL 116.0 ' DATE 04/21/95 I MIDDLE GROUND SHOAL PRESENT DEPTH 11994 DIST. KB TO BHF 38.4 DAY 30 LL,^6E PLATFORM 'A' FOOTAGE DRILLED NLTA LTH/YTD _/_ EST. DAY 22 WELL A24-01LE SIZE OF LAST CSG 7.000 LTA LTH/YTD / DAYS +/- WORK ORDER 723530 DEP. OF LAST CSG 10013 DAYS SINCE LAST LTA 746 SIDE TRACK _ WATER DEPTH 80 LAST BOP TEST 04/14/95 LAST CSG TEST 03/26/95 DRILLING FOREMAN: WELLS R V /FREDERICK DA BHA INSPECTION (CUM. ROT HRS) PRESENT ACTIVITY: CIRCULATING PP1 0 KILL SPEED 1330 8 30 PP2 0 KILL SPEED 1860 0 50 SUMMARY OF OPERATIONS (SHOW HOURS FOR EACH OPERATION) : 1.50 FINISH POOH WITH CLEAN OUT ASSY TIME (HRS) .50 LAYDOWN BHA • CUM. ROT. HRS 250.00 1.50 RIG UP TO RUN 5' LINER - HOLD SAFETY AND PROCEDURE MEETING ROTATING 5.50 PICK UP 5' LINER - MAKE UP FLOAT SHOE, 1 JT 5" (46.31') DEL VALVE MUD MOTOR FLOAT COLLAR, LANDING COLLAR, 61 JTS 5" (2758.58'), BAKER HYFLO LINER TRIPPING 6.50 HANGER - FILL LINER EVERY 5 JTS C & C 10.00 5.00 RIH WITH 5' LINER ON 3-1/2' DP - FILL DP EVERY 10 STDS TO TOW - RUN IN REAMING OPEN HOLE WITHOUT STOPPING TO FILL PIPE SURVEYS 10.00 PICK UP CEMENT HEAD WITH HARD LINES - BREAK CIRCULATION - TAG BOTTOM - JET , CIRCULATE AND CONDITION HOLE FOR CEMENT JOB - WORK PIPE - LOSING REPAIRS APPROX. 6 BPH 0 55 SPM - SLOW DOWN SPM AND MONITOR - NO FLUID LOSS 0 FISHING 30 SPM - CIRCULATE 3 COMPLETE CIRCULATIONS NIP UP/DOWN /BOP/WH • TESTING BOP /WH CASING DETAIL: SHOE 0 11994.00' RUNNING CASING 5.50 1 JT 5' 0 11992.52' CEMENTING FC 0 11946.21' PICKUP/LAY DOWN DS .50 LC 0 11944.65' INSPECT BHA 61 JTS 5' 0 11943.09' RIG UP/TEAR DOWN LINER HGR 0 9183.48' WAIT ON WEATHER/MAT TOL 0 9170.38' EVALUATION CORING (TURBECO TYPE "W' CENTRALIZERS INSTALLED EVERY 20') OTHERS 1.50 SWEPI ALASKA DAILY DRILLING REPORT PAGE 1 OF 1 RIG NAME PLATFORM "A' PROG. DEPTH 11943 ELEVAT. KB TO MSL 116.0 DATE 04/22/95 3 MIDDLE GROUND SHOAL PRESENT DEPTH 11994 DIST. KB TO BHF 38.4 DAY 31 Le.,,SE PLATFORM "A' FOOTAGE DRILLED NLTA LTH/YTD _/_ EST. DAY 22 WELL A24-01LE SIZE OF LAST CSG 7.000 LTA LTH/YTD _/_ DAYS +/- WORK ORDER 723530 DEP. OF LAST CSG 10013 DAYS SINCE LAST LTA 747 SIDE TRACK _ WATER DEPTH 80 LAST BOP TEST 04/14/95 LAST CSG TEST 03/26/95 DRILLING FOREMAN: WELLS R V /FREDERICK DA BHA INSPECTION (CUM. ROT HRS) PRESENT ACTIVITY: DRILLING CEMENT PP1 0 KILL SPEED 1530 0 30 PP2 0 KILL SPEED 2130 0 50 SUMMARY OF OPERATIONS (SHOW HOURS FOR EACH OPERATION) : .50 HOLD SAFETY AND PROCEDURE MEETING FOR CEMENT JOB TIME (HRS) 1.00 CIRCULATE TO DETERMINE FLUID LOSS 0 55 SPM - NO FLUID LOSS 0 40 SPM CUM. ROT. HRS 263.00 2.00 RIG UP HOWCO - PUMP 20 BELS MIN. OIL PREFLUSH - TEST LINES TO 5000# - ROTATING 13.00 PUMP 40 BBL 12.0 PPG SPACER - PUMP 448 SXS PREMIUM CEMENT, .2t CFR-3, MUD MOTOR 1 t HR-5, HALAD 344L, I.OSURF 300 - DISPLACE WITH S BBL SPACER, 5 BBL TRIPPING 6.00 PREFLUSH, 45 BBLS 11.9 PPG MUD, 23 BELS 16 PPG MUD, 45 BBLS 11.9 PPG C & C 2.50 MUD (4 BELS OVER) - BUMPED PLUG 0 35008 - BLEED OFF PRESSURE - ROTATE REAMING OFF HANGER - RIG DOWN CEMENT HEAD SURVEYS (RECIPROCATE PIPE UNTIL 65 BBLS CEMENT WAS PAST THE SHOE - SET PIPE IN JET TENSION - FINISHED PUMPING CEMENT) REPAIRS 1.00 POOH 30 STDS (SLOW) - MAKE UP TOP DRIVE ,, FISHING 1.50 CIRCULATE TO CLEAR PIPE - CHECK FLOW - PUMP DRY JOB - NIP UP/DOWN /BOP/WH 2.00 POOH WITH LINER SETTING TOOL - LAY DOWN LAST 9 JTS DP TESTING BOP /WH .50 MAKE UP CLEAN OUT ASSY WITH BIT #4RR RUNNING CASING 2.50 RIH - TAG CEMENT 0 7315' CEMENTING 2.00 13.00 BREAK CIRCULATION - DRILL CEMENT FROM 7315' TO 8760' PICKUP/LAY DOWN DS INSPECT BHA RIG UP/TEAR DOWN WAIT ON WEATHER/MAT EVALUATION CORING \Cte -o \2. • 2`l‘,0).°1 Debra Oudean Hilcorp Alaska, LLC AK_GeoTech 3800 Centerpoint Drive, Suite 100 Anchorage, AK 99503 Tele: 907 777-8337 JE,hiirp:►luwkn.l.L(. Fax: 907 777-8510 E-mail: doudean@hilcorp.com DATA LOGGED /P/201‘ M. K BENDER DATE: 5/13/2016 To: AOGCC Makana Bender RECEIVED 333 W. 7th Ave. Ste#100 Anchorage, AK 99501 MAY 13 Z DATA TRANSMITTAL AOGCC MGS-A24-01 LE Prints GAMAMA RAY CASING COLLAR PERFORATION LOG CD MGS_A24-01LE_PERF 11MAR16_LAS.zp 4/28/2016 10:37 AM zip Archive 75 KB MGS_A24-O1LE_PERF_11MAR16_mg.tt 4/28/2016 10:13 AM TIF File 4,505 KB SCANNEC► JUN 1 3 2016 Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to 907 777.8510 Received B72,2✓� Date: STATE OF ALASKA ALOKA OIL AND GAS CONSERVATION COMAION REPORT OF SUNDRY WELL OPERATIONS 1.Operations Abandon ❑ Plug Perforations❑ Fracture Stimulate ❑ Pull Tubing❑ Operations shutdown ❑ Performed: Suspend ❑ Perforate 0 Other Stimulate ❑ Alter Casing❑ Change Approved Program ❑ Plug for Redrill ❑ Perforate New Pool ❑ Repair Well Cl Re-enter Susp Well❑ Other: ❑ 2.Operator 4.Well Class Before Work: 5.Permit to Drill Number: Name: Hilcorp Alaska,LLC Development 0 Exploratory ❑ 195-012 3.Address: 3800 Centerpoint Drive,Suite 1400 Stratigraphic III Service ❑ 6.API Number: Anchorage,AK 99503 50-733-20258-01 7.Property Designation(Lease Number): 8.Well Name and Number: ADL0018754 MGS A24-01 LE 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): N/A Middle Ground Shoal/E,F and G Oil Pools 11.Present Well Condition Summary: \Jt GCC Total Depth measured 11,994 feet Plugs measured N/A feet 1, #•J true vertical 9,827 feet Junk measured N/A feet Effective Depth measured 11,941 feet Packer measured 9,824 feet true vertical 9,815 feet true vertical 8,572 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 370' 24" 370' 370' Surface 2,010' 13-3/8" 2,010' 1,830' 3,090 psi 1,540 psi Intermediate Production 10,013' 7" 10,013' 8,731' 8,160 psi 7,020 psi Liner 2,811' 5" 11,994' 9,805' 10,140 psi 10,490 psi Perforation depth Measured depth 10,048-11,784 feet True Vertical depth 8,761 -9,780 feet �� N 201 2-7/8" 6.5#/L-80 9,144'(MD) 8,014'(TVD) Tubing(size,grade,measured and true vertical depth) 2-3/8" 4.7#/N/L-80 9,902'(MD) 8,637'(TVD) Packers and SSSV(type,measured and true vertical depth) Baker FH Packer 9,824'(MD)8,572'(TVD) Baker FV-6 TRSCSSV 311'(MD)311'(TVD) 12.Stimulation or cement squeeze summary: Intervals treated(measured): N/A Treatment descriptions including volumes used and final pressure: N/A 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 6 9 19 748 205 Subsequent to operation: 7 9 37 804 178 14.Attachments(required per 20 AAC 25.070.25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations 0 Exploratory❑ Development El Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16.Well Status after work: Oil El Gas ❑ WDSPL❑ Printed and Electronic Fracture Stimulation Data Cl GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP❑ SPLUG❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: 316-064 Contact Dan Marlowe(907)283-1329 Email dmarlowe@hilcorp.corn Printed Name Stan W.Golis Title Operations Manager I_ Signature t.J C/ Phone (907)777-8356 Date $/i( t 17� 1 Ya-1/6' RBDMS U- MAR 'L 3 2016 Form 10-404 Revised 5/2015 Li/�� Submit Original Only II • MGS -01 LEor 28 • leg 4,A24 Conduct SCHEMATIC API No.: 50-733-20258-01 Spud:A24-01 2-15-74 Hilcorp Alaska,LLC A24-01LE 3-28-95 24"Conductor Csg @ 370' 0, 111 Surf Csg:13 3/8"61#K55 BTC. � Tbg:2 7/8"6.5#L80 8R Set 0-9,144' 2 3/8"4.7#N/L80 8R Set 9,144-9,902' Set @ 2,010'. 2 Stg Cmt w/3,450 sk. � Set 5-95. Top Job w/125 sk. GLM MD TVD PORT Ptro Psc Pso A24-01 Original Longstring(4-74): All, 1 2095' 1904' 12 925 886 950 7"29#N80 BTC. Set @ 10,888'. 2 3789' 3390' 12 910 867 913 Cmt w/2,100 sk.TOC @ 8,760'. 3 5132' 4548' 12 895 845 879 4 6158' 5397' 12 880 822 845 5 6867' 5998' 16 935 798 834 A24-01LE Sidetrack(3-95): 6 7448' 6510' 16 920 776 812 Window from 10,001-13' 7 7998' 7005' 16 905 754 788 Whipstock @ 10,001-21' 8 8544' 7502' 16 895 734 770 CIBP @ 10,021' 9 9097' 7977' ''/"(16)Orifice Valve KOP @ 10,013' 10 9744' 8505' Dummy Valve (2 7/8"0-50 GLM's#1-9&2 3/8"U-50 GLM#10) Liner:5"18#L80/P110 STL.Set • @ 9,183-11,994'. re Cmt w/448 sk. Baker FV-6 TRSCSSV(2.31"ID)@ 311' X-over 2 7/8"to 2 3/8"tbg @ 9,144' 19 Jts 2 3/8"4.7#8R tbg 0° 2 3/8"X Nipple @ 9,791'(1.875"ID) 1 Jt 2 3/8"4.78 8R tbg 5"Baker"FH"Packer @ 9,824'w/30K#shear 2 2 8R tbg 3XN 2 3/8"XN Profile Nipple @ 9,869'(1.791"ID) 1Jt23/8"4.7#8Rtbg /!� Modified Wireline Re-entry Guide @ 9,902' A24-01LE Sidetrack: New Perfs in 5"Liner: HK 1B: 10048'-10073' HK 1B: 10075'-10095' HI-HK: 10200'-10242' HK-HN: 10330'-10406' I/I HN-HR: 10426-10686' HR-HR2: 10790'-10918' HR2-HN2: 11016'-11187' HN2-HK2: 11358'-11548' HK2-HI2: 11564'-11610' HF2-HE2: 11682'-11713' HD2-HC2: 11736-11784' A24-01 Original Well: Old Perfs in 7"Csg: — GR-GS: 9663'-9720' HC-HD: 9966-10026' I, HC-HD: 10050'-10091' — HE-HF: 10113'-10133' I — HI-HK: 10187'-10215' HK-HN: 10245-10295' or HK-HN: 10306-10366' HN-HR: 10390'-10475' HN-HR: 10500'-10534' PBTD: 10,800'MD(9,404'ND) Notes TD:11,994'(9,827'ND) TD: 10,900'(9,484'ND) (CT Fish @ 10,559') Updated By:JLL 03/17/16 • Hilcorp Alaska, LLC Well Operations Summary Well Name Rig API Number Well Permit Number Start Date End Date MGS A 024-01LE E-Line 50-733-20285-01 195-012 3/10/16 3/11/16 Daily Operations: 03/10/2016-Thursday Platform operations meeting,tail gate safety meeting,JSA&permit to work.Weld pad-eye to deck. Make up ELU WH X- over flange to WH. HES ELU hands 2&3 arrives on helo. Platform orientation,safety meeting w/Crane Operator&crew. Rig up ELU. Pick up lubricator&dummy gun (11.5'TL X 1-9/16"OD spent gun) +GR log suite toolstring&rig to WHA. PT WH, Lub& BOP=250 LO/3500 HI-PASS.Open Swab Valve;Tubing Press=90 psi. RIH to 10,170' ELM;correlate log up. Log suite stops working on trip up. POOH; Failed knuckle joint in log suite verified @ surface. Lay down dummy gun. Replace failed log suite knuckle joint.Test all log subs w/meter-PASS. Pick up 10' perf guns(1-9/16"OD carrier, 1503 RAZOR XDP,6spf @ 60 deg phasing), rig to WHA&open swab valve.Tubing Press=90 psi, IAP=708 psi,OAP=21 psi. RIH to 10,164';Correlate Log up to 9,780'.Send LAS file for digital tie back.Correct depth to match digital tie back. RIH to 10,777.5' ELU counter depth (7.5'source to top perf). Fire gun with Top perf= 10,085'and Bottom perf= 10,095'. Post Perf Tbg Press=90 psi, IAP=708 psi,OAP=21 psi. POOH;Come to surface w/all shots fired. RD&lay down ELU lubricator stack. Nite cap WH w/swab, master&wing valves closed.Shut down for night. Job Ongoing; Final T/IA/OA= 90/711/21. 03/11/2016-Friday Platform Sim-ops mtg.Tail gate safety mtg,JSA& Permit to Work. RU HES ELU Lubricator& BOP stack. PU GR/CCL log suite&Perf Gun#2(10'X 1-9/16"OD carrier). Rig to WHA. Open swab valve. Initial T/IA/OA pressures= 150/241/21. RIH to 10,150' ELM. Log up to 9,750' ELM. Correlate depth to digital tie back from Run#1. RIH to 10,150'&PUH to 10,067.5' source depth (7.5'source to top perf). Fire gun&perf w/Top perf= 10,075'and Bottom perf=10,085'(6 spf @ 60 deg. phasing).T= 150 psi post perforation. POOH. Return to surface w/all shots fired. PU Perf Gun#3 (10'X 1-9/16"OD carrier). Rig to WHA.Open swab valve.Tbg Press=160 psi. RIH to 10,150' ELM. Log up to 9,750' ELM. Correlate depth. RIH to 10,150'& PUH to 10,055.5'source depth(7.5'source to top perf). Fire gun&perf w/Top perf= 10,063'and Bottom perf=10,073' (6 spf @ 60 deg. phasing).T= 160 psi post perforation. POOH. Return to surface w/all shots fired. PU Perf Gun#4(10'X 1-9/16"OD carrier). Rig to WHA.Open swab valve.Tbg Press= 160 psi. RIH to 10,150' ELM. Log up to 9,750' ELM.Correlate depth. RIH to 10,150'&PUH to 10,045.5'source depth (7.5'source to top perf). Fire gun&perf w/Top perf=10,053'and Bottom perf=10,063' (6 spf @ 60 deg. phasing).T= 160 psi post perforation. POOH. Return to surface w/all shots fired. PU Perf Gun#5 'X 1-9/16"OD carrier). Rig to WHA. Open swab valve.Tbg Press= 160 psi. RIH to 10,150' ELM. Log up to 9,750' ELM. Correlate depth. RIH to 10,150'&PUH to 10,040.5'source depth (7.5'source to top perf). Fire gun &perf w/Top perf= 10,048'and Bottom perf=10,053' (6 spf @ 60 deg. phasing).T= 160 psi post perforation. POOH. Return to surface w/all shots fired. Final T/IA/OA =160/243/21. Rig down and prep HES ELU package for boat load out to OSK. Fly crew to OSK.Job Ended. Pti of 7'4 Z evw �� 11/7; THE STATE Alaska Oil and Gas ®fA LAsKAL Conservation Commission _,_- 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 of ALASI‘Q' Main: 907.279.1433 Fax: 907.276.7542 � - (, 4 www.aogcc.alaska.gov Stan Golis I OS -, 0 la- Operations Manager `� Hilcorp Alaska, LLC 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Re: Middle Ground Shoal Field, E, F, and G Oil Pools, MGS A24-01 LE Permit to Drill Number: 195-012 Sundry Number: 316-064 Dear Mr. Golis: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Cathy . Foerster Chair DATED this 3 day of February, 2016. RBDMS G'- FEB 0 4 2016 oL&-- • 111 RECEIVEL STATE OF ALASKA FEB 01 2 16 ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS Dod 2--/V/4 20 AAC 25.280 AC, 1.Type of Request: Abandon ❑ Plug Perforations❑ Fracture Stimulate ❑ Repa r Well ❑ Operations shutdown❑ Suspend ❑ Perforate 0 Other Stimulate ❑ Pull Tubing ❑ Change Approved Program❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other. ❑ 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number. Hilcorp Alaska,LLC Exploratory ❑ Development 0, 195-012 3.Address: 3800 Centerpoint Drive,Suite 1400Stratigraphic ❑ Service i: 6.API Number. Anchorage,AK 99503 50-733-20258-01 7. If perforating: 8.Well Name and Number What Regulation or Conservation Order governs well spacing in this pool? CO 44 Will planned perforations require a spacing exception? Yes ❑ No 0 / MGS A24-01 LE - 9.Property Designation(Lease Number): 10. Field/Pool(s): ADL0018754 Middle Ground Shoal/E,F and G Oil Pools 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP(psi): Plugs(MD): Junk(MD): 11,994 - 9,827 • 11,941 9,815 3,200 psi None Casing Length Size MD TVD Burst Collapse Structural Conductor 370' 24" 370' 370' Surface 2,010' 13-3/8" 2,010' 1,830' 3,090 psi 1,540 psi Intermediate Production 10,013' 7" 10,013' 8,731' 8,160 psi 7,020 psi Liner 2,811' 5" 11,994' 9,805' 10,140 psi 10,490 psi Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 10-200-11,784 - 8,892-9,805 2-7/8"&2-3/8" 6.5#/L-80&4.7#N/L-80 9,144&9,902 Packers and SSSV Type: Packers and SSSV MD(ft)and TVD(ft): Baker FH Packer&Baker FV-6 TRSCSSV • 9,824'(MD)8,572'(TVD) &311'(MD)311'(TVD) 12.Attachments: Proposal Summary 0 Wellbore schematic 0 '13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch LI Exploratory ❑ Stratigraphic ❑ Development 0 • Service ❑ 14.Estimated Date for 15.Well Status after proposed work: 2/15/2016 Commencing Operations: OIL 0 . WINJ ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approval. Contact Dan Marlowe(907)283-1329 Email dmarlowe@hilcorp.com Printed Name Stan W.Golis Title Operations Manager Signature a•^ (104.•%•:o'' "l i Phone (907)777-8356 Date ' I6 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 3\ 4 — ot-Q `f Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: Post Initial Injection MIT Req'd? Yes ❑ No ❑ Spacing Exception Required? Yes ❑ No Subsequent Form Required: / , ,' .( ,/ APPROVED BY Approved by: p7`� COMMISSIONER THE COMMISSION Date:Z 3 - `[ Z -z i > 4 /C. RBDMS 0V FEB 0 4 2016 /' OpRv}cepfcfln, v4 SubmiForm and Form 10-403 Revised 11/2015 rd for 12 months from the date of approval. Attachments in Duplicate • • Well Prognosis Well: A-24-01LE Hilcarp Alaska,LLC Date: 01/28/2016 Well Name: MGS A24-01LE API Number: 50-733-20258-01 Current Status: Gas-Lifted producer Leg: Leg#4 South corner Estimated Start Date: February 15, 2016 Rig: N/A (E-Line) Reg. Approval Req'd? 403 Date Reg. Approval Rec'vd: Regulatory Contact: Juanita Lovett (8332) Permit to Drill Number: 195-012 First Call Engineer: Dan Marlowe (907) 283-1329 (0) (907) 398-9904 (M) Second Call Engineer: Trudi Hallett (907) 777-8323 (0) (907) 301-6657 (M) Current Bottom Hole Pressure: 2,538 psi @ 8,000'TVD 0.330 psi/ft datum 2016 PBU Maximum Expected BHP: 4,000 psi @ 8,000'TVD 0.490 psi/ft datum upper zone/offsets Maximum Potential Surface Pressure: 3,200 psi Using 0.1 psi/ft gradient 20 AAC 25.280(b)(4) Brief Well Summary Well Middle Ground Shoal A24-01LE is a gas-lifted oil well completed in the Hemlock zone.This project will add Hemlock sands not currently perforated. E-line Procedure: 1. MIRU E-line, PT lubricator to 3,500 psi Hi 250 Low. 2. RU e-line guns and perforate per program. Record tubing pressures before and after perforating run. -f K (6 3. RD E-line. 4. Turn well over to production. Attachments: 1. Current Wellbore Schematic 2. Proposed Wellbore Schematic • • BDP 2-28-14 Present Completion MGS A24-01 LE KB: 38' Cook Inlet,Alaska /t Water Depth:73'MSL Leg 4, Conductor 28 API No.: 50-733-20258-01 ,� Tbg:2 7/8"6.5#L80 8R Set 0-9,144' Spud: A24-01 2-15-74 A24-01 LE 3-28-95 2 3/8"4.7#N/L80 8R Set 9,144-9,902' Set 5-95. 24"Conductor Csg @ 370' GLM MD TVD PORT Ptro Psc Pso 1 2095' 1904' 12 925 886 950 Surf Csg: 13 3/8"61#K55 BTC. 2 3789' 3390' 12 910 867 913 Set @ 2,010'. 2 Stg Cmt w/3,450 sk. 3 5132' 4548' 12 895 845 879 Top Job w/125 sk. 4 6158' 5397' 12 880 822 845 5 6867' 5998' 16 935 798 834 6 7448' 6510' 16 920 776 812 A24-01 Original Longstring (4-74): 7 7998' 7005' 16 905 754 788 8 8544 7502' 16 895 734 770 7"29#N80 BTC. Set @ 10,888'. ' 9 9097' 7977' %"(16)Orifice Valve Cmt w/2,100 sk. TOC @ 8,760'. 10 9744' 8505' Dummy Valve (2 7/8"D-SO GLM's#1-9&2 3/8"U-SO GLM#10) A24-01LE Sidetrack(3-95): Window from 10,001-13' 01# Baker FV-6 TRSCSSV(2.31"ID)@ 311' . Whipstock @ 10,001-21' X-over 2 7/8"to 2 3/8"tbg @ 9,144' CIBP @ 10,021' 19 Jts 2 3/8"4.7#8R tbg KOP @ 10,013' 2 3/8"X Nipple @ 9,791'(1.875" ID) A 1 Jt 2 3/8"4.7#8R tbg Liner:5"18#L80/P110 STL.Set / 5"Baker"FH"Packer @ 9,824'w/30K#shear @9,183-11,994'. 1Jt23/8"4.7#8Rtbg Cmt w/448 sk. / 2 3/8"XN Profile Nipple @ 9,869'(1.791"ID) 1 it 2 3/8"4.7#8R tbg Modified Wireline Re-entry Guide @ 9,902' A24-01LE Sidetrack: New Perfs in 5" Liner: HI-HK: 10200'-10242' HK-HN: 10330'-10406' HN-HR: 10426'-10686' H R-H R2: 10790'-10918' HR2-HN2: 11016-11187' HN2-HK2: 11358'-11548' H K2-H 12: 11564'-11610' H F2-H E2: 11682'-11713' H D2-H C2: 11736'-11784' A A24-01 Original Well: Old Pens in 7"Csg: GR-GS: 9663'-9720' HC-HD: 9966'-10026' HC-HD: 10050'-10091' HE-HF: 10113'-10133' HI-HK: 10187'-10215' HK-HN: 10245'-10295' HK-HN: 10306'-10366' 0< HN-HR: 10390'-10475' AI* 4 HN-HR: 10500'-10534' PBTD: 10,800'MD(CT Fish @ 10,559') TD: 11,994'(9,827'ND) TD: 10,900'(9,484'TVD) • MGS A24-01 LE • Leg 4,Conductor 28 II 11111 PROPOSED API No.: 50-733-20258-01 Spud:A24-01 2-15-74 Hilcorp Alaska,LLC A24-01LE 3-28-95 24"Conductor Csg @ 370' Surf Csg:13 3/8"618 K55 BTC. / Tbg:2 7/8"6.5#L80 8R Set 0-9,144' 2 8" Set @ 2,010'. 2 Stg Cmt w/3,450 sk. / 4.7#N/L80 8R Set 9,144-9,902' Set 5 Top Job w/125 sk. 5-95. / MD TVD PORT Ptro Psc Pso A24-01 Original Longstring(4-74): % o 1 2095' 1904' 12 925 886 950 7"29#N80 BTC. Set @ 10,888'. 2 3789' 3390' 12 910 867 913 Cmt w/2,100 sk.TOC @ 8,760'. 3 5132' 4548' 12 895 845 879 4 6158' 5397' 12 880 822 845 5 6867' 5998' 16 935 798 834 A24-01LE Sidetrack(3-95): 6 7448' 6510' 16 920 776 812 Window from 10,001-13' 7 7998' 7005' 16 905 754 788 Whipstock @ 10,001-21' 8 8544' 7502' 16 895 734 770 CIBP @ 10,021' 9 9097' 7977' %"(16)Orifice Valve KOP @ 10,013' 10 9744' 8505' Dummy Valve (2 7/8"D-SO GLM's#1-9&2 3/8"U-50 GLM#10) Liner:5"18#L80/P110 STL.Set @ 9,183-11,994'. Cmt w/448 sk. Baker FV-6 TRSCSSV(2.31"ID)@ 311' X-over 2 7/8"to 2 3/8"tbg @ 9,144' 19 Jts 2 3/8"4.78 8R tbg / 2 3/8"X Nipple @ 9,791'(1.875"ID) / 1 it 2 3/8"4.78 8R tbg 5"Baker"FH"Packer @ 9,824'w/30K#shear 1 it 2 3/8"4.78 8R tbg 2 3/8"XN Profile Nipple @ 9,869'(1.791"ID) 1 it 2 3/8"4.78 8R tbg Modified Wireline Re-entry Guide @ 9,902' If A24-01LE Sidetrack: / ''New Perfs in 5"Liner: HK 1B: 10048'-10073'(Proposed) �'0 HK 1B: 10075'-10095'(Proposed) - K: 10200'-10242' HK-HN: 10330'-10406' HN-HR: 10426'-10686' H R-H R2: 10790'-10918' HR2-HN2: 11016'-11187' H N 2-H K2: 11358'-11548' H K2-H)2: 11564'-11610' H F2-H E 2: 11682'-11713' H D 2-H C2: 11736'-11784' A24-01 Original Well: Old Perfs in 7"Csg: GR-GS: 9663'-9720' r HC-HD: 9966'-10026' — HC-HD: 10050-10091' HE-HF: 10113'-10133' ----- HI-HK: 10187'-10215' HKK-H-HN: 10245'-10295' HK-HN: HN-HR: 10306'-10366' 10390'-10475' HN-HR: 10500'-10534' 4 Notes PBTD: 10,800'MD(9,404'TVD) (CT Fish @ 10,559') TD:11,994'(9,827'TVD) TD: 10,900'(9,484'ND) Updated By:JLL 01/29/16 XHVZE Pages NOT Scanned in this Well History File This page identifies those items that were not scanned during the initial scanning project. They are available in the original file and viewable by direct inspection. /¢_¢'""(~//¢'~' File Number of Well History File PAGES TO DELETE RESCAN Complete Color items - Pages: Grayscale, halftones, pictures, graphs, charts- Pages: Poor Quality Original- Pages: [] Other- Pages: DIGITAL DATA [] Diskettes, No. [] Other, No/Type OVERSIZED [] Logs of various kinds [] Other COMMENTS: Scanned b~ianna Vincent Nathan Lowell Date:/~,,::~, Is~ ~ [] TO RE-SCAN Notes: Re-Scanned by: Bevedy Dianna Vincent Nathan Lowell Date: Is~ • UNSCANNED, OVERSIZED MATERIALS AVAILABLE: 0~~, FILE # To request any/all of the above information, please contact: Alaska Oil & Gas Conservation Commission ! 333 W. 7th Ave., Ste. 100 k Anchorage, Alaska 99501 Voice (907) 279-1433 Fax (907) 276-7542 • Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Thursday, July 10, 2008 7:48 AM To: 'Paul_Figel(a>ctoenergy.com' Cc: Jeff_Gasch@xtoenergy.com Subject: RE: A24-01 LE (195-012) and ~42~;~65-A~4~ Thanks Paul. That helps fill in the blanks. Tom -----Original Message----- From: Paul_Figel@xtoenergy.com [mailto:Paul_Figel@xtoenergy.com] Sent: Thursday, July 10, 2008 5:33 AM To: Maunder, Thomas E (DOA) Cc: Jeff_Gasch@xtoenergy.com Subject: Re: A24-O1LE (195-012) and A21-12XX (205-071) Tom, The records are correct as we have not done anything with A24-O1LE in terms of plugging or re-drilling the well as A21-12xx. A24-O1LE has been shut in for the past +3 years. We do not have compressor capacity to gas lift this well as the other wells were demanding more lift gas as the water cut was increasing on the newer West Flank wells. I'm in Ft Worth through this week in Well Review. If you have any more questions, please contact Jeff Gasch at 423-682-8873 as he is overseeing Alaska. Thanks, Paul Paul Figel Engineering Manager XTO Energy Inc. Midland, TX Office: 432-620-6743 Mobile: 432-553-5217 Fax: 432-687-0862 ~~P~lN~i~ JUL ~. ~ ZDG~ "Maw Thomas E (DOA) " <tom.maunder@ala ka.gov> 07/09/2008 06:14 PM ul Figel @XTOenergy.com> A24-OlLE (195-012) and A21- (205-071) To cc Subject 1 Page 1 of 1 Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Wednesday, July 09, 2008 3:14 PM To: 'Paul Figel' Subject: A24-01LE (195-012) and Paul, I was looking through the on-line well files and I have a couple of questions regarding these wells. A sundry 305-115 was issued in early May 2005 to plug back A24-01LE to allow the redrilling of A21-12. I don't find any report of the work authorized by 305-115 in that well file and the "XX" appended to A21-12 means that permit expired. I also found A24-01 LNXX (200-160) listed as cancelled. Can you or one of your engineers help sort this out? According to the production record, A24-01 LE has Not produced since mid October 2004. Thanks in advance. I look forward to your reply. Tom Maunder, PE AOGCC ~~~~~ J ~ L ~ "3 2008 7/9/2008 ) ) -$~.') \~'-" ,r' "I'). ':\ ;).,,0:1 ¡'.i"'" i II J...;¡ ,~' "'~"\ : il ~"à\ ): i J: \~~ i !L i ':'-.~ ~ '("':IF iI"':':ìJr ,,: 11 i :11:, !¡l,~ ¡I: :\:j 'Li' : 'I l ~ ( L-.:..~ I'~ '1-:::::1 ,11 il:: fWil:I!'! Þ , '\J' ' 'I il ',,,,,i.',., :U l~\ ij-r¡ j, Trl, \. ~ '.', f ;¡ II'~ \ i (.' ,,<-,j,~ :1 :1 Ul' \:\ ~ " ,,' I '" :, """"'" ¡ ,_I '._-U /01 1/ 1~ '~ ,d\ U~\.J FRANK H. MURKOWSKI, GOVERNOR AI~A~KA. OIL AlWD GAS CONSERVATION COMMISSION 333 W. pH AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Bobby Smith Drilling Operations Manager XTO Energy, Inc. 3000 North Garfield, Suite 175 Midland, Texas 79705 "a,(70 11/ Re: Middle Ground Shoal A24-01LE Sundry Number: 305-115 SCANNED M¡\Y 1 1 2.0(J5 Dear Mr. Smith: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. Please provide at least twenty-four (24)- hours notice for a representative of the Commission to witness any required test. Contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person :~~e:~~~ppeal a Commission de~periOr 0 unless rehearing has been ( / ;e olnK. DA TED this~ day of May, 2005 Encl. ~TO ~kRGY ) ) April 27, 2005 RECEIVED APR 2 9 Z005 Mr. John Norman, Chair Alaska Oil and Gas Conservation Commission 333 West 7th Ave., Suite 100 Anchorage, Alaska 99501 Alaska Oil & Gas Cons. Commission Anchorage RE: Application for Sundry Approval; P&A ofMGS Well A24-01LE, Cook Inlet, Alaska Dear Mr. Norman, XTO Energy, Inc. hereby applies for Sundry Approval of its plan to permanently abandon the existing perforations in Middle Ground Shoal Wen A24-0 I LE to allow the sidetracking of that well to drill A21-12. The application for a Permit to Drill A21-12 is submitted under separate cover. The anticipated commencement date of this work is approximately Mayl8, 2005. The purpose of the planned sidetrack is to develop reserves in a thus-far untapped area of the Hemlock Reservoir on the East Flank of the Middle Ground Shoal structure. While the current mechanical condition of the wellbore is good (see the attached wellbore schematic), the well has been shut in since October 24, 2004 due to low production. At the time it was shut in the well was producing 6 BOPD, 22 BWPD and 55 MSCFGD. There are no remaining economic reserves recoverable by this wellbore. To accomplish the abandonment, the existing completion will be pulled and the well plugged by placing cement from TD to a minimum of 150' above the topmost perforation in the 5" liner. After the cement integrity is tested, the well will be sidetracked from the 7" casing above the 5" liner top to a new location in the reservoir. Pertinent information attached to this application includes the following: I) Form 10-403 Application for Sundry Approval 2) A summary of the proposed abandonment procedure 3) A schematic showing the current condition of the wellbore 4) A schematic showing the proposed abandonment If you have any questions or require additional information, please contact me at (432) 620-6718 or Bill Penrose at (907) 258-3446. ('1 f-' ! (0\ ¡ L ! t,~ L I '1-"/ , \ ,"" l ,'\1 ! 1 . ~",i f \ !..../! l ¡ ,: r-\ : _ XTOEnergyInc.· 3000N.Garfield· Suite175· Midland,Texas79705· (915)682-8873· Fax:(915)687-0862 ) , Mr. John Norman Page 2 Sincerely, XTO ENERGY, INC. frftr i ~ Bobby L. Smith Drilling/Operations Manager enclosures cc: Bill Penrose I. 1 RECEIVED APR 2 9 2005 Alaska Oil & Gas Cons. Commission Anchorage 'I , ; " , t)~ ~ / " ...) 5 'tdO:5 , STATE OF ALASKA) $'/3 / .' ./ ALAS..J OIL AND GAS CONSERVATION COMM'vSION /-.S APPLICATION FOR SUNDRY APPROVARECEIVED 20 AAC 25.280 Abandon LJ Suspend U Operational shutdown U Perforate U APRWjjivg ~O~nnular Dispos. U Alter casing 0 Repair well 0 Plug Perforations 0 Stimulate 0 Time Exte&ion tT Other 0 Change approved program 0 Pull Tubing 0 Perforate New Pool 0 Re-AlHkILiite&iGiSVGlbrW Commission 2. Operator Name: 4. Current Well Class: 5. Pern1trMtÞm~a~ember: XTO Energy, Inc. Development 0 Exploratory 0 195-012 3. Address: Stratigraphic 0 Service 0 6. API Number: Its¡ _3 1. Type of Request: 3000 North Garfield, Suite 175, Midland TX 79705 7. KB Elevation (ft): 50-733-20258-01 9. Well Name and Number: 105' ASL MGS A24-01 LE 8. Property Designation: 10. Field/Pools(s): ADL-18756 Middle Ground Shoal 11. Total Depth MD (ft): 11 ,994' Casing Structural Conductor Surface Intermediate Total Depth TVD (ft): 9,805' Length PRESENT WELL CONDITION SUMMARY Effective Depth MD (ft): Effective Depth TVD (ft): 11,994' 9,805' Plugs (measured): None Junk (measured): None Collapse 370' 2,010' Size MD TVD 24" 370' 370' 13-3/8 " 2,010' 1,830' Burst N/A 3,090 psi N/A 1,540 psi Production 10,013' 7" 10,013' 8,731' 8,160 psi 7,020 psi Liner 2,811' 5" 11,994' 9,805' 10,140 psi 10,490 psi Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 10,200' -11,784' 8,892' - 9,805' 2-7/8" UN-80 9,902' Packer: Baker FH, SSSV: Baker FV-6 Packers and SSSV MD (ft): Packer @ 9,824', SSSV @ 311' 12. Attachments: Description Summary of Proposal LJ Detailed Operations Program 0 BOP Sketch 0 14. Estimated Date for Commencing Operations: 16. Verbal Approval: Commission Representative: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. 5/20/2004 13. Well Class after proposed work: Exploratory 0 Development 0 Service 0 15. Well Status after proposed work: Oil 0 Gas 0 Plugged 0 Abandoned 0 WAG 0 GINJ 0 WINJ 0 WDSPL 0 Date: Printed Name Bobby Smith Signature ¡~ L ~ Phone Title (432) 620-6718 COMMISSION USE ONLY Contact Bill Penrose 258-3446 Drilling/Operations Manager Date Conditions of approval: Notify Commission so that a representative may witness Sundry Number: ~1 /) S' ' /IS" Plug Integrity 1ll BOP Test ~ Mechanical Integrity Test 0 Location Clearance 0 Other: '-D't""\Ö c\- 1''''7 ck"'l: '">-~ \ ~O V ~ S\.{< s\«. ~ \ d ~~..s":,(, \E:\c<;" -\-- , RBDMS 8FL M¡1,!' 0 4 7005 Subsequent Form APProvG COMMISSIONER BY ORDER OF THE COMMISSION Date: s~~a~ INSTRUC1;,IG~~',OI\j ~E¥~~~9 .' '¡. "', 1 \ N,\ \ ¡ \,¡ ) ) XTO Energy, Inc. MGS ~4-01LE RECEIVED APR 2 9 Z005 Alaska Oil & Gas Cons. Commission Anchorage Summary P&A Procedure 1. Move the rig over the well, R/U wireline and RIH with severing charge for cutting 2-3/8" tubing. Cut the 2-3/8" tubing at 9,775'MD (approximately 16 feet above the top 2-3/8" x-nipple). POH and RID wireline. 2. Kill well by circulating 9.0 ppg water-base mud down the tubing, through the tubing cut at 9,775' and up the annulus. While circulating, weight up the mud in small increments until it is heavy enough to kill the well. 3. Install BPV, NID tree, N/U BOPE. Test BOPE to 5,000 psi. [Note: at the discretion of the Drilling Supervisor and AOGCC Inspector (if present), blind rams will be tested after tubing is pulled from hole if there is a chance a gas bubble will settle under BPV, making it difficult or dangerous to release.] Pull BPV. 4. MID landing joint to tubing hanger, back out lock-down screws and pull hanger loose from tubing spool. Ensure well is dead and POH with tubing, checking for NORM while POH. LID tubing and completion jewelry and send to shore. 5. MID a Baker fishing assembly for retrieving the 2-3/8" tubing stub and Baker FH retrievable packer. RIH to the top of the cut off tubing at 9,775', engage the fish and jar the packer loose (packer is set to shear at 30,000 lbs, but has been in the hole for ten years). 6. CBU and POH, checking for NORM. Send fish to shore. 7. Make a 5" casing scraper run to 11,994' TD. POH. ~ 8. Rill with a 5" cement retainer and set at 1 0,750' (between the bottom HI perf and the top H2 perfs). 9. Inject 10 bbls of fresh water followed by 22 bbls of cement below the retainer. Cement to be mixed as follows: 107 sx Class G + 0.4% bwoc R-3 + 0.3% bwoc CD-32 + 0.5% bwoc FL-63 + 1 gal/lOOsx FP-6L + 43.70/0 fresh water: Slurry Wt. Slurry Yield 15.8 ppg 1.15 cflsk \' ... ~., I I" . \ I C ~ I, ) ) RECEIVED APR 2 9 2005 Mix Water 4.92 gps Alaska Oil & Gas Cons. Commission Note: If the perforations below the retainer will not take the cement, un_st~horage from the retainer and lay the cement on top of it, ensuring that the top of cement is at least 150' above the top HI perf (i.e., at or above 10,050'). Skip Step 10 below. 10. After pumping cement through the retainer, un-sting from the retainer and mix and pump 13 bbls of cement mixed as above. Drop a 4" wiper dart behind the cement and displace with mud while slowly pulling up the drill pipe to lay a cement plug from 11,750' to 10,050'. 11. POH with drillpipe. 12. MIU a 7" test packer and Rlli to 8,800'. Set the test packer and pressure test the liner lap and cement across perfs to 3,000 psi for 30 minutes. 13. POH and proceed with sidetrack procedure to drill A21-12. ) RECEIVED APR 2 9 Z005 PLF 5-2-02 Present Completion ~ ~ . Alaskl(Oil & GlIs€Cons. Commission Water ~.aÕê' MSL J J Tbg: 2 7/8" 6.5# L80 8R Set 0 - 9,144' 2 3/8" 4.7# N/L80 8R Set 9,144 - 9,902' Set 5-95. J GLM MO TVO PORT ptro Psc Pso 1 2095' 1904' 12 925 886 950 J 2 3789' 3390' 12 910 867 913 J 3 5132' 4548' 12 895 845 879 4 6158' 5397' 12 880 822 845 J 5 6867' 5998' 16 935 798 834 6 7448' 6510' 16 920 776 812 J 7 7998' 7005' 16 905 754 788 8 8544' 7502' 16 895 734 770 J 9 9097' 7977' 20 985 710 769 10 9744' 8505' 1/4" Orifice Valve '\ / (27/8" O-SO GLM's #1-9 & 2 3/8" U-SO GLM #10) ') ~'TO ~kRGY MGS A24-01 LE Cook Inlet, Alaska Leg 4, Conductor 28 API No.: 50-733-20258-01 Spud: A24-01 2-15-74 A24-01 LE 3-28-95 24" Conductor Csg @ 370' Surf Csg: 133/8" 61# K55 BTC. Set @ 2,010'. 2 Stg Cmt wI 3,450 sk. Top Job wI 125 sk. A24-01 Original Longstring (4-74): 7" 29# N80 BTC. Set @ 10,888'. Cmt wI 2,100 sk. TOC @ 8,760'. A24-01 LE Sidetrack (3-95): Window from 10,001-13' Whipstock @ 10,001-21' CIBP @ 10,021' KOP @ 10,013' Li ner: 5" 18# L80/P 11 0 STL. Set @ 9,183 -11,994'. Cmt wI 448 sk. L 1- L L (- ~ Baker FV-6 TRSCSSV (2.31" 10) @ 311' X-over 2 7/8" to 2 3/8" tbg @ 9,144' 19 Jts 2 3/8" 4.7# 8R tbg 23/8" X Nipple @ 9,791' (1.875" 10) 1 Jt 2 3/8" 4.7# 8R tbg 5" Baker "FH" Packer @ 9,824' wI 30K# shear 1 Jt 2 3/8" 4.7# 8R tbg 2 3/8" XN Profile Nipple @ 9,869' (1.791" 10) 1 Jt 2 3/8" 4.7# 8R tbg Modified Wireline Re-entry Guide @ 9,902' A24-01 LE Sidetrack: New Perfs in 5" Liner: HI-HK: 10200'-10242' HK-HN: 10330'-10406' HN-HR: 10426'-10686' HR-HR2: 10790'-10918' HR2-HN2: 11016'-11187' HN2-HK2: 11358'-11548' HK2-HI2: 11564'-11610' HF2-HE2: 11682'-11713' H02-HC2: 11736'-11784' A24-01 Original Well: Old Perfs in 7" Csg: GR-GS: 9663'-9720' HC-HD: 9966'-10026' HC-HD: 10050'-10091' HE-HF: 10113'-10133' HI-HK: 10187'-10215' HK-HN: 10245'-10295' HK-HN: 10306'-10366' HN-HR: 10390'-10475' HN-HR: 10500'-10534' TO: 11,994' (9,805' TVD) PBTD: 10,800' MO (CT Fish @ 10,559') TD: 10,900'(9,484' TVO) ~~O ~kRGY MGS A24-01 LE Cook Inlet, Alaska Leg 4, Conductor 28 API No.: 50-733-20258-01 Spud: A24-01 2-15-74 A24-01 LE 3-28-95 ) Proposed Abandonment . 24" Conductor Csg @ 370' Surf Csg: 13 3/8" 61# K55 BTC. Set @ 2,010'. 2 Stg Cmt wi 3,450 sk. Top Job wi 125 sk. A24-01 Original Longstring (4-74): 7" 29# N80 BTC. Set @ 10,888'. Cmt wi 2,100 sk. TOC @ 8,760'. A24-01 LE Sidetrack (3-95): Window from 10,001-13' Whipstock @ 10,001-21' CIBP @ 10,021' KOP @ 10,013' Liner: 5" 18# L80/P11 0 STL. Set @ 9,183 - 11,994'. Cmt wi 448 sk. TOC: ±10,050' L Cmt Retainer: / :.:.. 10,750' \- L (~ ~ TO: 11,994' (9,805' TVO) ) RECEIVED APR WJP 5-21-05 2 9 2005 Alam Oil & fiì8~ Cons. Commission Water O~\Uio1igl¥1SL A24-01 LE Sidetrack: New Perfs in 5" Liner: HI-HK: 10200'-10242' HK-HN: 10330'-10406' HN-HR: 10426'-10686' HR-HR2: 10790'-10918' HR2-HN2: 11016'-11187' HN2-HK2: 11358'-11548' HK2-HI2: 11564'-11610' HF2-HE2: 11682'-11713' H02-HC2: 11736'-11784' A24-01 Original Well: Old Perfs in 7" Csg: GR-GS: 9663'-9720' HC-HO: 9966'-10026' HC-HD: 10050'-10091' HE-HF: 10113'-10133' HI-HK: 10187'-10215' HK-HN: 10245'-10295' HK-HN: 10306'-10366' HN-HR: 10390'-10475' HN-HR: 10500'-10534' PBTO: 10,800' MD (CT Fish @ 10,559') TO: 10,900' (9,484' TVO) " " ~ $ BEEN O1'4 OR BEFORE W STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR ,SUNDRY APPROVAL 1. Type of Request: [x] Abandon G Pool [ ] Suspend [ ] Plugging [ ] Time Extension [ ] Perforate [ ] Alter Casing [ ] Repair Well [ ] Pull Tubing [ ] Variance [ ] Other [ ] Change Approved Program [ ] Operation Shutdown [ ] Re- Enter Suspended Well [ ] Stimulate P! ~ ~,- 2. Name of Operator 5. Type of well: 6. Datum Elevation ([CF or KB) [X] Development Cross Timbers Operating Company [ ] Exploratory 116' KB 3. Address [ ] Stratigraphic 7. Unit or Property Name 210 Park Avenue, Ste. 2350, Oklahoma City, OK 73102 [ ] Service Middle Ground Shoal 4. Location of well at surface 8. Well Number PLATF A, LEG 4, 6OND 28, 1564' FSL & 378' FEL Sec. 11, TSN, R13W, SM A24-01LE At top of productive interval 9. Permit Number @ 9960' MD-KB; 6' FNL & 2098' FWL Sec. 12, TSN, R13W, SM 95-12 / 95-054 At effective depth 10. APl Number 50-733-20258-01 At total depth 11. Field and Pool @11,994' MD-KB; 339' FSL & 1968' FEL Sec. 1, TSN, R13W, SM MGS G Pool 12. Present well condition summary Total depth: measured 11,994 feet Plugs (measured) true vertical 9,828 feet Effective depth: feet Junk (measured) feet Casing Length Size Cemented MD TVD Structural Conductor 370' 24" -- 370' 370' Surface 2,010' 13-3/8" 1300 sx 2,010' 1,830' Intermediate Production 10,888' 7" 2100 sx 10,888' 9,466' Liner 2,811' 5" 448 sx 9,170' top 8,036' 11944' btm 9,797' Perforation depth: measured 10,200'-11,786' True vertical 8,892'-9,771' Tubing (size, grade and measured depth) 2-7/8" 6.5# LB0 EUE 8rd @ 9,902' Packers and SSSV (type and measured depth) 9,823'ORIGINAL 13. Attachments IX] Description of Sumary Proposal [X] Detailed Operations Program [*] BOP Sketch *On file w/AOGCC 14. Estimated date for commencing operation 15. Status of well classification as: 11/17/00 16. If proposal was verbally approved [X] Oil [ ] Gas [ ] Suspended Name of approver Date Approved Service Contact Engineer Name/Number: Bill Penrose (907)258-3446 Prepared By Name/Number; Susan Sudduth (405)319-3213 17. I hereby certify th_at the foregoing is true and correct to the best of my knowledge Commission Use Only Conditions of Approval: Notify Commission/so representative may witness IApproval No.. ~.,,~-~. Plug integrity,./ BOP Test v Location Clearance Mechanical Integrity Test ~ Subsequent form required 10- /~0 L)Ri(__~INAL SIGNED ~¥ Approved by order of the Commission D -FSy!O, Seamo,FIt Commissioner Date Form 10-403 Rev. 06/15/88 Sub~it In 7'riplic-ate -1- MIDDLE GROUND SHOAL WELL NO. A24-01LN WELL PROGRAM The Middle Ground Shoal (MGS) A24-01LN will be a re-drill of the existing well A24-01LE. The objective is the Hemlock reservoir. The current perforations will be isolated using a cement retainer at 10,125' MD and a cement plug from +/- 10,075' to 11,944'. The well will be directionally drilled out of the existing 7" casing to 11,730' MD (9,242' TVD). Kick off point will be at 7,500' MD. The well will be drilled to a depth of 10,300' MD and a 5" liner cemented in place. A 4-1/8" hole will be drilled to a depth of 11,730' MD (9,242' TVD) and a 3-1/2" slotted liner run. The Hemlock will be perforated and produced. -2- Cross Timbers Operating Company MGS A24-01LN Sidetrack Procedure Move rig over well. Install BPV, N/D tree, N/U BOPE. Test BOPE to 5,000 psi. P/U on tubing, pull packer loose and displace well to 9.0 ppg water-base drilling fluid POH with tubing, checking for NORM while POH. L/D tubing and completion jewelry and send to shore. P/U 3-1/2" drill pipe, RZH and abandon perforations in the 5" liner as follows (Notify the AOGCC at least 24 hrs in advance): Set a cement retainer at 10,125'MD (75' above the top-most perforation) in the 5" liner and squeeze sufficient cement below it to fill the 5" liner to 11,944'MD (5" liner shoe). Pull out of retainer and place a 75' cement cap on top. Pull up, reverse out and WOC. Weight-test cement plug with 15,000#. POH. RIH with 7" one-trip whipstock. Orient and set whipstock at 7,500'MD and mill a window in 7" casing using a 6" mill. Directionally drill 6" hole from 7,500' to 10,300'MD. Run and cement 5", 17.95#, L-80 STL liner at 10,300'MD with TOL at approximately 7,200'MD (-300' of lap). Clean out liner to float collar and pressure-test casing/liner lap to 3,000 psi for 30 minutes Drill out liner shoe and displace well to 9.0 ppg oil-base drilling fluid Drill approximately 20' of new hole and conduct leak-off test Directionally drill 4-1/8" hole from 10,300' to 11,730'MD. Run 3-1/2", 9.2#, L-80, STL slotted liner with liner-top packer at 11,730'MD with TOL at approximately 10,000' (-300' of lap). Displace well to filtered Inlet water Run 2-3/8", 4.7#, N-80, 8rd EUE completion with gas lift design. -3- Pickle inside of tubing with HC1/xylene and circulate inhibited filtered Inlet water into annulus before setting packer. N/D BOPE, N/U tree. Test tree to 5,000 psi. Release rig -4- Cross Timbers Operating Company MGS A24-01 LE Cook Inlet, Alaska Leg 4, Conductor 28 APl No.: 50-733-20258-00 Present Completion Spud: 24" Conductor Csg @ 370' Surf Csg: 13 3/8", 61 lb, K55, BTC. Set @ 2010'. Cmt'd w/1300 sx Prod Csg' 7", 29 lb N80, BTC. Set @ 10888'. Cmt w/2100 sx. Window from 10001'-10013' Whipstock @ 10001'-10021' CIBP @ 10021' KOP @ 10013' 5", 18#, L80/P110, STL flush jt Liner @ 11994' Cmt'd w/448 sx. TOL @ 9170' jrs 6/29/99 KB: 105' Water Depth: 73' MSL Tbg: 2 7/8", 6.5#, L80 EUE 8rd (0-9144') 2 3/8", 4.7#, N80/L80 EUE 8rd (9144'- 9902') (9 - 2 7/8" D-SO GLM's & 1 - 2 3/8" U-SO GLM) Baker "FV-6" TRSCSSV w/"X" Profile @ 311' GLM MD TVD PORT Ptro Psc Pso 1 2095' 1904' 12 925 886 950 2 3789' 3390' 12 910 867 913 3 5132' 4548' 12 895 845 879 4 6158' 5397' 12 880 822 845 5 6867' 5998' 16 935 798 834 6 7448' 6510' 16 920 776 812 7 7998' 7005' 16 905 754 788 8 8544' 7502' 16 895 734 770 9 9097' 7977' 20 985 710 769 10 9744' 8505' 1/4" Orifice Valve X-over From 2 7/8" to 2 3/8" tbg @ 9144' 1 jt 2 3/8", 4.7#. N80/L80 EUE 8rd tbg Otis "X: Nipple @ 9791' (1.875" ID) 1 jt tbg Baker "FH" Packer @ 9824' w/30KJ¢ shear 1 jt tbg Otis "XN" Profile Nipple @ 9869' (1.791" ID) 1 jt tbg Modified Wireline Re-entry Guide @ 9902' New Perfs in 5" Liner: HI-HK: HK-HN: HN-HR: HR-HR2: HR2-HN2: HN2-HK2: HK2-HI2: HF2-HE2: HD2-HC2: Old Perfs in 7" Csg: 10200'-10242' 10330'-10406' 10426'-10686' 10790'-10918' 11016'-11187' 11358'-11548' 11564'-11610' 11618'-11714' 11731 '-11786' GR-GS: 9663'-9720' HC-HD: 9966'-10026' HC-HD: 10050'-10091' HE-HF: 10113'-10133' HI-HK: 10187'-10215' HK-HN: 10245'-10295' HK-HN: 10306'-10366' HN-HR: 10390'-10475' HN-HR: 10500'-10534' TD: 11944' PBTD: 10613' MD (Underreamer fish @ 10559') TD: 10900' -5- Cross Timbers Operating Co. MGS A24-01LN Spud: Planned 10/1/2000 (Original wellbore spudded 2/15/ 74 Sidetrack A24-01LE was spudded 5/10/95.) Proposed: 5" 17.95# LB0 STL liner: 7200- 10,300'. Cmt'd Proposed Completion J Surf Csg: 13 3/8" 61# K55 BTC (~ 2,010'. Prod Csg: 7", 29#, N80 BTC. Set @ 10,888'. Cmt'd w/2100 sx G. Proposed Tbg: 2 3/8" 4.7# N80 8R EUE (~ 9900' w/Bkr DB pkr assembly and GLMs Sidetrack A24-01LE: Whipstock 10,001' -10,021 '. K©P 10,013'. 5" 18# N-80/P110 FJ liner 9,170- 11,994'. Proposed- 3-1/2" 9.2# L80 STL liner: 10,000- 11,730' MD. Cmt'd Proposed TD 11,730' TOC 10,613' Orig TD 10900' Proposed Cmt Retainer @ 10,125'. 75' cmt on top and cmt TD 11944' to 11,944'. H I-HK: 10200'- 10242' H K-H N: 10330'- 10406' H N-H R: 10426'-10686' HR-HR2: 10790'-10918' HR2-HN2: 11016'-11187' HN2-HK2: 11358'-11548' HK2-HI2: 11564'-11610' HF2-HE2: 11618'-11714' H D2-HC2: 11731 '-11786' Cross Timbers Operating Company September 27, 2000 Mr. Blair Wondzell, Sr. Petroleum Engineer Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501-3192 Re: Application for Sundry Approval' A24-01LE - Abandon Existing Hemlock Completion (G Pool} Dear Mr. Wondzell: Cross Timbers Operating Company hereby applies for approval to abandon the existing Hemlock completion ("G" Pool perfs) in preparation to drill a second sidetrack of the existing A24-01 wellbore. The existing sidetrack will be abandoned per AOGCC regulations before the second sidetrack is commenced. Please find attached information as required for your review. Pertinent information attached to the application includes the following: 1) 2) 3) 4) Form 10-403 Application for Sundry Approval; Description of Summary Proposal; and Detailed Operations Program. Diagrams and descriptions of the BOP equipment to be used as required by 20 AAC 25.035 (a)(1) and (b) were previously submitted to your office and are on file. If you have any questions or require additional information, please contact me at (405)319-3213. Sincerely, CROSS TIMBERS OPERATING COMPANY Susan 1. Sudduth Sr. Engineering Technician Drilling Department Mid-Continent Division enclosures CC: Bill Penrose Doug Marshall Mike Langeler Charles Pope 210 Park Avenue, Suite 2350, Oklahoma City, Oklahoma 73102-5605 (405) 232-4011 Fax (405) 232-5538 17,,E RM IT ......................... 95-'0 i 2 95 ..... 0 Ix '~ 95-012 AZ."'[/'1~ .,. , , ii ...... .i.j" 10014-11945 AIZ?~' .,.....;,,,.i .~ "!.. 10014-'-' I1945 A...].:i/,2~ .,,,_.:.:~.~h~,¥:-'.: L 10014 .... I 0 a. / © o/' 95 ~:.. ~.,, . / ":' 8//.95 CJ 44 / ~... 95-'0 I © 95-012 BHCLE:'/GR i..L' 100i4-1188,q. -': : " PISDNGR .. L" I0014-11985 i 0 4~/' 28//9.5 0/4. / 28/' 95 95--~017 'rAP E L Z S T · 10 - 407 DAILY ~qELL OPS /' 'j/i /' Are (:ii"-,/ ditch samples r'equi'r'ed,°. yes (no .And r'ecei,¢eu-"?,, Was 'the we'li cor'ed? yes ,no: Analys'¥s ~; descr'i'pt.:'¥on (~ Received? "/e s r" :,-~ C 0 "1: V e d , /t / /" y 0 :~.; J"l C, STATE OF ALASKA I ALASKA OIL AND GAS CONSERVATION COMMISSION ~ WELL COMPLETION OR RI=COMPLETION REPORT AN~ 1. Status of Well Classification of Service ~V~ii¢..~.~ o,,_ E! O 0 s,:.,:..v,c,: 0 ,, 2. Name of Operator 7. Permit Number $hell Western E&P Inc, 95-12 / 95-054"~" 3. A~dress (N6K 5237) 8. APINumber P.0. BOX 576, Houston, TX 77001-0576 s0- 733-20258-01- 4. Location of well at surface 9. Unit or Lease Name r'cc,--T ~.,~.-.~.~:,iTi.~.~ PLATF A, LEG 4, COND 28, 1564' FSL & 378' FEL Sll, T8N, R13r~, ~'.-M,: .... , MIDDLE GROUND SHOAL At Top Producing Interval! ..?~_~'~-' .To 10. Well Number Ca 9960' MD-KB; 6' FNL & 2098' FWL S12, T8N, R13W, S.M.it vsm~l~o A24'O1LE At Total depth Ca 11,994' HD- KB; 339' FSL & 1968' FEL S1, TSN, R13W, S. H ~ ....... ~'~.'.~_ 11. Field and Poot 5' Elevati°ninfeet(indicateKB'DF'et°')116, KB 16' LeaseDesignationandSerialN°'ADL 18754 HCG "6" P00L "~ 12_ Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband 1 15. Water Depth, if offshoreI 16. No. of Completions I I 3-28-95 4-17-95 5-10-95 80' feet MSLI $IN6LE 17. Total Depth (MD * TVD) 8. Plug Back Depth (MD + TVD) 19. Directional Survey J20. Depth where SSSV set J 21. Thickness of Permafrost 11,994' HD: 9828'~ YES [] NO [] I TRSCSSV Ca 304' feetMDI N/A 22_ Type Electric or Other Logs Run BITF/AIT/RH£/I DT/£NI 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 24" 60NDR 0 370' 13-3/8" 61# K-55 0 2010' 17-1/2" 1300 $X 7" 29~ N-80 0 10,888' 9-7/8" 2100 SX 5" 18~ N-80 9183' 11,994' 6" 448 SX - - - 24. Perforations open to Production (MD + TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 2-7/S" a¢lO~.' 9823' 10,200-10,242' (4 5PF) tt,-~/t--it, e~o' (4 10,330-10,406' (4 SPF) l~,est-~,'/~4.'(~,) 2s. ACID, FRACTURE, CEMENT SQUEEZE. ETC. 10,426'10,686' (4 SPF) It,'/-~-i~0'~'(,~¢') DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 10,790-10,918' (4 SPF) N/A 11,016-11,187' (4 $PF) i(,~87_-u,'us' 11,358-11,548' (4 SPF) ~,-~,. 27. PRODUCTION TEST Date First Production I Method of Operation (Flowing, gas lift, etc.) R-10-q.~I ('-,AC~ I fFT Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE I GAS-OIL RATIO 7-02-95 24 TEST PERIOD 25 59 65 128[ 2360 Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 90 740 24-HOUR RATE 34.7 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. NONE Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE - 49 - 29. 30. GEOLOGIC ,,i~r~KERS FORMATION TESTS Include interval tested, pressure data, all fluids recovered and gravity, GOR, NAME MEAS. DEPTH TRUE VERT. DEPTH and time of each phase. SEE A1 rACHED GEOLOGIC MARKER SUMHARY 31. L~ST OF ATTAOHMENTS MORNING REPORTS, DIRECTIONAL SURVEY, GEOLOGIC MARKER SUMltARY 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ~, I/~//~-(xly. z.~ ~)~ ~ m. S. NJI~)Y Title "Gm- ASSE-r AD, IN. Date ~ ~ I/ INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, Other-explain. Form 10-407 R7~ NAME - PLATFORM 'A" PROG. ~TH ~ ~ MIDDLE GROUND SHOAL PRESE! EPTH LEASE PLATFORM "A" FOOTAGE DRILLED WELL A24-01LE SIZE OF LAST CSG 7.000 WORK ORDER 723530 DEP. OF LAST CSG 10888 WATER DEPTH 80 /FREDERICK DA SIDE TR~CK DRILLING FOREMAN: WELLS R V PRESENT ACTIVITY: RIGGING UP SUMMARY OF OPERATIONS (SHOW HOURS FOR EACH OPERATION) : 6.00 RIG SECURED FOR AIT BBQ 11943 18.00 - -- ELEVAT. KB TO MSL 116 0 DATE DIST. KB TO BHF -- DAY NLTA LTH/YTD / · EST. DAY LTA LTH/YTD / DAYS +/- DAYS SINCE LAST LTA 220 LAST BOP TEST 03/22/95 LAST CSG TEST BHA INSPECTION (CUM. ROT HRS) PP1 e KILL SPEED PP2 ~ KILL SPEED BLEED DOWN GAS FROM INJECTION-LINE AND REMOVE FROM ANNULUS VALVE - MAKE UP CIRC. LINES AND PUMP FIW DOWN ANNULUS - LET TBG FLOW TO PROD. HEADER AND MONITOR WHILE RIGGING UP - PREPARE RIG TO SKID EAST - CH3%NGE HATCH COVERS_ON SUB DECK - CENTER RIG OVER A24-01LE - SET STAIRS AND HAND RAILS - CLEAN PITS - REPAIR VALVES ON SUCTION LINE - SET PIPE RACK AND CAT WALKS IN PLACE - INSTALL SHOCK HOSE NOTE: THANKS TO ALL AIT MANAGEMENT FOR APPROVING THE BBQ - EVERYONE H3%D AN GREAT TIME. SPECIAL THANKS TO RICK CASHIONAND HIS WEATHERFORD FOLKS FOR ALL THE LONG HOURS AND HARD WORK THEY PUT INTO 'MAKING IT HAPPEN". EVERYONE THAT WAS THERE IS MOST APPRECIATIVE!!!! TIME (HRS) CUM. ROT. HRS ROTATING MUD MOTOR TRIPPING C&C REAMING SURVEYS JET REPAIRS FISHING NIP UP/DOWN /BOP/WH TESTING BOP /WH RUNNING CASING CEMENTING PICKUP/LAY DOWN DS INSPECT BHA RIG UP/TEAR DOWN WAIT ON WEATHER/MAT EVALUAT I ON CORING OTHERS 18.00 6.00 SWEPI ALASKA DAILY DRILLING REPORT PAGE 1 OF 1 RI~ NAME PLATFORM 'A" PROG. DEPTH 11943 ELEVAT. KB TO MSL ) MIDDLE GROUND SHOAL PRESENT DEPTH DIST. KB TO BHF Lbs-.SE PLATFORM "A' FOOTAGE DRILLED NLTA LTH/YTD WELL A24-01LE SIZE OF LAST CSG 7.000 LTA LTH/YTD WORK ORDER 723530 DEP. OF LAST CSG 10888 DAYS SINCE LAST LTA . _ . . SIDE TRACK WATER DEPTH 80 LAST BOP TEST DRILLING FOREMAN: WELLS R V /FREDERICK DA PRESENT ACTIVITY: PREPARE TO TEST BOP'S 116.0 DATE · DAY / EST. DAY / DAYS 221 LAST CSG TEST BHA INSPECTION (CUM. ROT HRS) PP1 ~ KILL SPEED PP2 ~ KILL SPEED SUMMARY OF OPERATIONS (SHOW HOURS FOR EACH OPERATION) : 24.00 CLOSE SSSV AND INSTALL BPV - HOLD SAFETY/PROCEDURE MEETING FOR NIPPLE DOWN/UP - BLEED OFF ANNI/LUS GAS TO PRODUCTION HEADER UNTIL LESS THAN 60 PSI THEN BLEED OFF TO ON-DECK TANK - REMOVE TREE ASSY - INSTALL RISER - NIPPLE UP BOP'S - REFAB 4" AND 6" CHOKE LINES - CHANGE OUT SUCTION VALVE IN MUD PIT - MAKE UP 4' DRAIN HOSE AND ROUTE TO SLOP TANK IN WELLHF2~D ROOM - FILL PITS WITH FIW - CHANGE SHAKER SCREENS - MODIFY BELL NIPPLE - PREPARE TO TEST BOP'S NOTE: SPECIAL THANKS GOES OUT TO SCHLUMBERGER FOR ALLOWING EPOCH MUD LOGGERS TO SET UP IN THEIR DOG HOUSE. THIS IS GOING TO SAVE A LOT OF TIME, EFFORT AND $$$$. THANKS FOR BEING A PROACTIVE AIT MEMBER!!! TIME (HRS) CUM. ROT. HRS ROTAT I NG MUD MOTOR TRIPPING C & C REAMING SURVEYS JET REPAIRS FISHING NIP UP/DOWN /BOP/WH TESTING BOP /WH RUArN I NG CA~ I NG CEMENTING PICKUP/LAY DOWN DS INSPECT BHA RIG UP/TEAR DOWN WAIT ON WEATHER/MAT EVALUAT I ON o3/23/9s 1 22 24.00 RIG NAME PLATFORM UAU FI"'O MIDDLE GROUND SHOAL L PLATFORM aaa WELL A24-O1LE WORK ORDER 723530 SIDE TRACK DRILLING FOREMAN: WELLS R V PROG. DEPTH 11943 PRESENT DEPTH FOOTAGE DRILLED SIZE OF LAST CSG 7.000 DEP. OF LAST CSG' 10888 WATER DEPTH 80 /FREDERICK DA PRESENT ACTIVITY: JAR ON TUBING HANGER SUMMARY OF OPERATIONS (SHOW HOURS'FOR EACH OPERATION) : 4.00 TEST BOP'S 6.50 2.50 2.00 9.0~ PI ALASKA DAILY DRILLING REPORT !~-. PAGE 1 OF 1 ELEVAT. KB TO [~L 116.0 DATE DIST. KB TO BHF DAY 2 NLTA LTH/YTD __/ EST. DAY 22 LTA LTH/YTD / DAYS +/- DAYS SINCE LAST LTA 222 LAST BOP TEST ~/2...~/9~ LAST CSG TEST BHA INSPECTION (CUM. ROT HRS) PP1 @ KILL SPEED ___ PP2 @ KILL SPEED @ INSTALL DRIP PAN AROUND BELL RIPPLE - FINISH CLEANING UP IN SUB AROUND HATCH COVERS AND DECK - BOLT DOWN AND SILICONE WEAR PLATE FOR 6" AUGER AND INSTALL GUARDS - CUT HOLE IN HATCH COVER FOR MOUSE HOLE AND PATCH HOLE FROM LAST WELL - MIX 90 BBLS 9.2 PPG FLUID AND FILL TRIp TANK BACK-OUT TUBING HANGER SET SCREWS - ATTEMPT TO UNSEAT HANGER - HANGER WILL NOT COME. LOOSE' PICK UP. (3) 4-3/4" DC~S. 4-3~4" UP J~RS. I JT 3-1/2" DP AND XO - MAKE UP TO TUBING RANGER JAR ON TUBING HANGER - PULL 175K TO 180K BEFORE JARS GO OFF - JAR 10 TIMES AND COOL OFF JARS WITH WATER - CONTINUE JARRING - BLEED OFF ANNULUS GAS AND MONITOR - CONTINUE JARRING · _ . THANKS TO JOE ROSWELL AT HALLIBURTON - JOE IS GOING TO SAVE THE 300 BBL DIESEL TANK WE HAD OUT HERE FOR THE LAST WELL FOR US TO USE ON THIS WELL. THIS gILL SAVE AFE $$ THE COST OF A TANK CLEANING. EVERY LITTLE BIT HELPSlll THANKS JOEIll T I ME (}IRS)_ .... CUM. ROT. HAS ROTATING MUD MOTOR TRIPPING C & C REAMING SURVEYS JET REPAIRS FISHING NIP UP/DOWN /BOP/I/I{ TESTING BOP RUNNING CASING CEMENTING PICKUP/LAY DOWN DS INSPECT BHA RIG UP/TEAR DOWN WAIT ON WEATHER/MAT EVALUATION CORING OTHERS 4.00 20.00 SWEPI ALASKA DAILY DRILLING REPORT PAGE 1 OF 1 RT~ NAME PLATFORM "A" PROG. DEPTH 11943 D MIDDLE GROUND SHOAL PRESENT DEPTH Lr..~SE PLATFORM "A" FOOTAGE DRILLED WELL A24-01LE SIZE OF LAST CSG 7.000 WORK ORDER 723530 DEP. OF LAST CSG 10888 SIDE TRACK WATER D~TH 80 . DRILLING FOREMAN: WELLS R V /FREDERICK DA PRESENT ACTIVITY: CHANGE PIPE RAMS SUMMARY OF OPERATIONS (SHOW HOURS FOR EACH OPERATION) : 1.oo CONTINUE JARRING ON TUBING HANGER .50 LAYDOWN HWDP AND JARS - MAKE UP HWDP AND BUMPER SUB 1.50 JAR UP ON TUBING HANGER WITH MECHANICAL BUMPER SUB ASSY ELEVAT. KB,TO MSL 116.0 DATE 03/25/95 DIST. KB TO BHF DAY 3 NLTA LTH/YTD / EST. DAY 22 LTA LTH/YTD / DAYS +/- DAYS SINCE LAST LTA 223 LAST BOP TEST 03/23/95 LAST CSG TEST BHA INSPECTION (CUM. ROT HRS) PP1 ~ KILL SPEED ~ PP2 ~ KILL SPEED ~ 1.00 LAY DOWN BUMPER SUB - MAKE UP X-O, 1JT HWDP, FISHING JARS, 1 4-3/4 DC, ACCELERATOR, 1JT HWDP .50 JAR ON HANGER - HANGER CAME LOOSE ON SECOND HIT 1.00 LAY DOWN ASSY - FILL ANNT/LUS .50 PULL ON 2-7/8 TUBING AND RELEASE PRODUCTION PACKER 3.00 CLOSE PIPE RAMS - CIRCULATE FIW ~ 1-2 BPM - RETURNS TO PRODUCTION HEADER 4.00 OPEN WELL UP - STILL OIL AND GAS RETURNS - CIRCULATE FIW WITH RETURNS TO INJECTION WELL VIA GAS BUSTER - CHECK FLOW - PUMP 9.0 PPG PILL 10.50 POOH - LAY DOWN PRODUCTION STRING .50 CLEAN RIG FLOOR - CHANGE PIPE RAMS TO 3-1/2 TIME (HRS) CUM. ROT. HRS ROTATING MUD MOTOR TRIPPING 10.50 C & C 7.00 REAMING SURVEYS JET REPAIRS FISHING NIP UP/DOWN /BOP/WH TESTING BOP /WH RUNNING CASING CEMENTING PICKUP/LAY DOWN DS 2.50 INSPECT BHA RIG UP/TEAR DOWN WAIT ON WEATHER/MAT SWEPI A3.~KSKA DAILY DRILLING REPORT PAGE 1 OF 1 RIG NAME PLATFORM "Ar PROG. DEPTH 11943 ,D MIDDLE GROUND SHOAL PRESENT DEPTH b~,~SE PLATFORM "A' FOOTAGE DRILLED WELL A24-01LE SIZE OF LAST CSG 7.000 WORK ORDER 723530 DEP. OF LAST CSG 10888 SIDE TRACK WATER DEPTH 80 ELEVAT. KB TO MSL 116.0 DATE DIST. KB TO BHF DAY NLTA LTH/YTD / EST. DAY LTA LTH/YTD / DAYS +/- DAYS SINCE LAST LTA 224 LAST BOP TEST 03/23/95 LAST CSG TEST 03/26/95 22 DRILLING FOREMAN: WELLS R V PRESENT ACTIVITY: TIH WITH RTTS /FREDERICK DA SUMMARY OF OPERATIONS (SHOW HOURS FOR EACH OPERATION) : 2.50 CHANGE PIPE RAMS - STRAP ANI) CALIPER MILL BHA ASSY 3.50 TEST BLIND RAMS AND PIPE RAMS - PERFORM ACCUMULATOR TIME TEST - INSTALL WEAR RING AND LOCK DOWN BHA INSPECTION (CUM. ROT HRS) PP1 · KILL SPEED ~ PP2 % KILL SPEED ~ 1.50 MAKE UP BHA - WINDOW MILL, CASING SCRAPER, WATERMELON MILL, BS WITH FLOAT, 6 DC'Sf UP JARSf DOWN JARS 7.50 RIH TO 10040' - FILL PIPE ~ 5500' - POOH 17 STANDS - PICK 51 JTS 3-1/2 DP 1.50 CIRCULATE WITH FIW - RA'rURNS TO INJECTION WELL VIA GAS BUSTER 1.50 CHECK FLOW - PUMP PILL 4.00 POOH WITH MILL 'AND SCRAPER ASSY - SLM 1.00 MAKE UP CIRCULATING-VALVE AND RTTS 1.00 RIH WITH RTTS NOTE: FIRE AI2~RM ~ 8:30 PM - FALSE ALARM - SMOKE DETECTOR ON 1ST FLOOR ZONE 2 - WELL WAS SECURED IN ONE MINUTE - PERSONNEL REPORTED TO REC. ROOM WITH AIR PACKS AND FLOAT SUITS - GOOD RESPONSE TIME;- TIME (HRS) CUM. ROT. HRS ROTAT I NG MUD MOTOR TRIPPING 12 . 50 C & C 3.00 REAMING SURVEYS JET REPAIRS FISHING NIP UP/DOWN /BOP/WH TESTING BOP /WH 3.50 RUNNING CASING CEMENT I NG PICkUP/LAY DOWN DS 2.50 INSPECT BHA RIG UP/TEAR DOWN WAIT ON WEATHER/MAT EVALUAT I ON CORING OTHERS 2.50 SWEPI ALASKA DAILY DRILLING REPORT PAGE 1 OF 1 RIG NAME PLATFORM "A" PROG. DEPTH 11943 ~ MIDDLE GROUND SHOAL PRESENT DEPTH b~E PLATFORM "A" FOOTAGE DRILLED WELL A24-01LE SIZE OF L~ST CSG 7.000 WORK ORDER 723530 DEP. OF LAST CSG 10888 SIDE TRACK __ WATER DEPTH 80 ELEVAT. KB TO MSL 116.0 DATE DIST. KB TO BHF DAY NLTA LTH/YTD / EST. DAY LTA LTH/YTD / DAYS +/- DAYS SINCE LAST LTA 225 LAST BOP TEST p3/23/95 LAST CSG TEST o3/27/95 5 22 DRILLING FOREMAN: WELLS R V PRESENT ACTIVITY: SET WHIPSTOCK /FREDERICK DA SUMMARY OF OPERATIONS (SHOW HOURS FOR EACH OPERATION) : 3.50 FINISH TIH WITH RTTS ASSY 1.00 SET PACKER AND TEST CASING TO 2000# FOR 30 MIN. - HELD OK .50 CHECK FOR FLOW - PUMP DRY JOB 4.00 POOH WITH RTTS ASSY BHA INSPECTION (CUM. ROT HRS) PP1 ~ KILL SPEED PP2 % KILL SPEED 4.50 RIG UP SWS - HOLD SAFETY AND PROCEDURE MEETING - RIH WITH BAKER CIBP - SET PLUG TOP ~ 10011' - POOH - RIG DOWN SWS 1.00 MAKE UP WHIPSTOCK AND ORIENTING SUB 8.00 RIH WITH WHIPSTOCK ASSY TO 9878' 1.50 MAKE UP TOP DRIVE - BREAK CIRCULATION AND ORIENT WHIPSTOCK - SET WHIPSTOCK - HANGER BOLT SHEARED @ 8K TIME (HRS) CUM. ROT. HRS ROTAT I NG MUD MOTOR TRIPPING 15.50 C & C 1.00 REAMING SURVEYS JET REPAIRS FISHING NIP UP/DOWN /BOP/WH TESTING BOP /WH RUNNING CASING CEMENTING PICKUP/LAY DOWN DS 1.00 SWEP~ .4~SKA DAILY DRILLING REPORT RIG NAME PLATFORM 9 MIDDLE GROUND SHOAL Lr~SE PLATFORM WELL A24-01LE WORK ORDER 723530 SIDE TRACK DRILLING FOREMAN: WELLS R V PRESENT ACTIVITY: MILLING WINDOW PROG. DEPTH 11943 PRESENT DEPTH 10007 FOOTAGE DRILLED SIZE OF LAST CSG 7.000 DEP. OF LAST CSG 10888 WATER DEPTH 80 /FREDERICK DA 116.0 PAGE 1 OF 1 ELEVAT. KB TO MSL DATE DIST. KB TO BHF DAY NLTA LTH/YTD / EST. DAY LTA LTH/YTD / DAYS +/- DAYS SINCE LAST LTA 226 LAST BOP TEST 03/23/95 LAST CSG TEST BHA INSPECTION (CUM. ROT HRS) PP1 ~ KILL SPEED 230 PP2 ~ KILL SPEED 520 SUMMARY OF OPERATIONS (SHOW HOURS FOR EACH OPERATION) : 1.00 FINISH SETTING WHIPSTOCK - SET AT 10021' DRILL PIPE MEASUREMENT 4.50 TOP DRIVE THROTTLE NOT WORKING PROPERLY ~ TROUBLE SHOOT AND REPAIR 1.50 CIRCULATE RETUP,~NS THRU GAS BUSTER 1.00 MILL CASING WINDOW WITH STARTER MILL ASSY - FROM 10001' TO 10003' - CIRCULATE WITH CLEAN FIW - RETURNS TO DISPOSAL WELL 1.50 CHECK FLOW - PUMP PILL - CUT & SLIP 100' DRILL LINE - SERVICE RIG AND TOP DRIVE 4.00 POOH WITH STARTER MILL ASSY .50 LAY DOWN STARTER MILL - MAKE UP 6" WINDOW MILL AND WATERMELON MILL 4.50 RIH WITH MILL ASSY #2 - FILL PIPE ~ 5000' 1.50 CIRCUT0%TE RE'IVJRNS THRU GAS BUSTER TIME (HRS) o3/28/95 6 22 4.00 MILL CASING WIN-DOW FROM 10003' TO 10007' 30 CUM. ROT. HRS 5.50 ROTATING 5.50 MUD MOTOR TRIPPING 8.50 C & C 2.50 REAMING SURVEYS JET REPAIRS 4.50 FISHING NIP UP/DOWN /BOP/WH TESTING BOP /WH RUNNING CASING CEMENTING PICKUP/LAY DOWN DS .50 INSPECT BHA RIG UP/TEAR DOWN WAIT ON WEATHER/MAT EVALUATION CORING OTHERS 2.50 SWEPI AIJL~KA DAILY DRILLING REPORT PAGE 1 OF 1 RIG NAME PLATFORM "A" FIELD MIDDLE GROUND SHOAL E PLATFORM "A" W~ A24-01LE WORK ORDER 723530 SIDE TRACK PROG. DEPTH 11943 PRESENT DEPTH 10023 FOOTAGE DRILLED 23 SIzE OF LAST CSG 7~000 DEP. OF L~T CSG 10888 WATER DEPTH 80 ELEVAT. KB TO MSL 116.0 DATE 03/29/95 DIST. KB TO BHF DAY 7 NLTA LTH/YTD / EST. DAY 22 LTA LTH/YTD / DAYS DAYS SINCE LAST LTA 227 LAST BOP TEST 03/23/95 LAST CSG TEST 03/26/95 DRILLING FOREMAN: WELLS R V PRESENT ACTIVITY: CIR~TE BOTTOMS UP /FREDERICK DA SUMMARY OF OPERATIONS (SHOW HOURS FOR EACH OPERATION) : 7.00 MILL CASING WINDOW TO 10013' 3.50 CHECK FLOW - POOH WITH MILL ASSY #2 1.00 LAYDOWN 1 JT 3-1/2 DP, WATERMELON MILL AND STARTER MILL - PICKUP WINDOW MILL, 2 WATERMELON MILLS, BS WITH FLOAT A1TD 1 JT H~DP 4.00 RIH WITH MILL ASSY ~3- 1.00 CIRCULATE BOTTOMS UP THRU GAS BUSTER 4.00 MILL AND DRESS OFF WINDOW FROM 10013' TO 10023' (10' OPEN HOLE) TOP OF WINDOW @ 10000' o BOTTOM OF WIh~OW @ 10013' 3.50 DISPLACE FIW WITH WITH OIL BASE MUD - CHECK FOR FLOW - CIRCULATE BOTTOMS UP ROTATING PARAMETERS AS FOLLOWS: ON BOTTOM WITH FIW - RPM'S=70 - AMPS=400-500 - WGT/UP=220 DOWN=135 ON BOTTOM WITH OBM - RPM'S=70 - AMPS=300-400 - WGT/UP=185 DOWN=140 OFF BOTTOM IN CASING WITH FIW - RPM'S=70 - AMPS=425-500 OFF BOTTOM IN CASING WITH OBM - RPM'S=70 - AMPS=300 BHA INSPECTION (CUM. ROT HRS) PPi @ KILL SPEED PP2 ~ KILL SPEED 230 ~ 30 520 ~ 50 TIME (HRS) CUM. ROT. HRS 16.50 ROTATING 11.00 MUD MOTOR TRIPPING 7.50 C & C 4.50 REAMING SURVEYS JET REPAIRS FISHING NIP UP/DOWN /BOP/WH TESTING BOP /WH RLrNNING CASING CEMENTING PICKUP/LAY DOWN DS 1.00 INSPECT BHA RIG UP/TEAR DOWN RIG NAME PLATFORM "A" PROG. DEPTH 11943 ) MIDDLE GROUND SHOAL PRESENT DEPTH 10111 L~E PLATFORM "A" FOOTAGE DRILLED 88 WELL A24-01LE SIZE OF LAST CSG 7.000 WORK ORDER 723530 DEP. OF LAST CSG 10888 SIDE TRACK WATER DEPTH 80 DRILLING FOREMAN: SELTZ R H /FREDERICK DA PRESENT ACTIVITY: KILL WELL SWEF 'J~SKA DAILY DRILLING REPORT SUMMARY OF OPERATIONS (SHOW HOURS FOR EACH OPERATION) : 1.50 CLEAN PIT #3 AFTER MIN OIL DISPLACEMENT .50 FILL TRIP TANK - CHECK FLOW - PUMP DRY JOB 3.00 TOOH FOR MOTOR 3.00 BHA - L/D MILLING BHA - P/U MOTOR ASSEMBLY 3.50 TIH - FILL PIPE · 4900' PAGE 1 OF 1 ELEVAT. KB TO MSL DATE DIST. KB TO BHF 38.4 DAY NLTA LTH/YTD / EST. DAY LTA LTH/YTD / DAYS +/- DAYS SINCE LAST LTA 724 03/30/95 8 22 LAST BOP TEST 03/23/95 LAST CSG TEST 03/26/95 BHA INSPECTION (CUM. ROT HRS) 1.50 ROTARY DRILL FROM 10,023' TO 10,032' (NOTE; NO PROBLEM GOING OUT OR BACK IN WINDOW) 1.00 SHUT IN WELL & CIRC OUT GAS (TRIED TO CIRC. OUT WITHOUT SHUTTING IN - WELL TRIED TO BELCH OVER BELL NIPPLE) .50 ROTARY DRILL FROM 10,032' TO 10,035' 5.00 ORIENT & DRILL W/MOTOR FROM 10,035' TO 10,111' 4.50 CHECK WELL FOR FLOW - FLOWING 3 BBL/HR - SHUT WELL IN & MONITOR PRES- SURES, 660 PSI DP - 680_ CSG - BLEED PRESSURE & PULL'TO SHOE (1 STND) - WEIGHT UP PITS TO 11.0 #/GAL (USING STORED 14.0 #/GAL MUD) - CIRC & KILL WELL. NOTE; TOOK ON 36,891 GAL DIESEL FUEL FROM M/V CHAMPION BACKLOADED BOAT WITH MISC. DRILLING EQUIPMENT REC. (3) BASKETS GROCERIES FROM HELICOPTER PP1 ~ KILL SPEED 900 @ 30 PP2 ~ KILL SPEED 1850 * 50 TIME (HRS) CUM. ROT. HRS 21.00 ROTATING 2.00 MUD MOTOR 2.50 TRIPPING 6.50 C & C 1.50 REAMING SURVEYS 2.50 JET REPAIRS FISHING NIP UP/DOWN /BOP/WH TESTING BOP /WH RUNNING CASING CEMENTING PICKUP/LAY DOWN DS 3.00 INSPECT BHA RIG UP/TEAR DOWN WAIT ON WEATHER/MAT EVALUAT I ON CORING OTHERS 6.00 SWEPI ALASKA DAILY DRILLING REPORT PAGE 1 OF 1 RIG NAME PLATFORM "A" 9 MIDDLE GROUND SHOAL Lo~SE PLATFORM "A" WELL A24-01LE WORK ORDER 723530 - SIDE TRACK DRILLING FOREMAN: SELTZ R H PRESENT ACTIVITY: MAKE UP BHA PROG. DEPTH PRESENT DEPTH FOOTAGE DRILLED SIZE OF LAST CSG DEP. OF LAST CSG WATER DEPTH 11943 ELEVAT. KB TO MSL 116.0 DATE 03/31/95 10230 DIST. KB TO BHF 38.4 DAY 9 119 NLTA LTH/YTD / EST. DAY 22 7.000 LTA LTH/YTD / DAYS +/- 10888 DAYS SINCE LAST LTA .725 80 LAST BOP TEST 03/31/95 LAST CSG TEST 03/26/95 /FREDERICK DA BHA INSPECTION (CUM. ROT HRS) PP1 @ KILL SPEED 900 @ 3__90 PP2 ~ KILL 'SPEED 1850 @ 5___q0 SUMMARY OF OPERATIONS (SHOW HOURS FOR EACH OPERATION) : 1.50 FINISH CIRCUIJ~TING AND KILLING WELL WITH 11.0 PPG MUD 50 OPEN WELL - CHECK FLOW 50 MOTOR DRILL FROM 10111' TO 10125' 00 ROTATE DRILL FROM 10125' TO 10225' 50 MOTOR DRILL FROM 10225' TO 10230' 00 CHECK FLOW - PUMP PILL - POOH WITH BIT #1 00 LAY DOWN MWD - STAND BACK BHA 00 TEST BOP'S 00 MAKE UP BHA WITH BIT #2 BIT #1 CONDITION: 5-6-BT-A-F-6-SD-HRS BEARING FAILURE IN CONES #2 AND #3 - EXTENSIVE SHIRT TAIL DAMAGE - BEARING FAILURE DUE TO COMPENSATOR PLUGS FALLING OUT - DUE TO BIT BEING ROTATED IN CASING WINDOW TIME (HRS) CUM. ROT. HRS 33.00 ROTATING 8.00 MUD MOTOR 4.00 TRIPPING 4 . 00 C & C 2.00 REAMING SURVEYS JET RE PAI RS FISHING NIP UP/DOWN /BOP/WH TESTING BOP /WH 4.00 RUNNING CASING CEMENT I NG PICKUP/LAY DOWN DS 2.00 INSPECT BHA RIG UP/TEAR DOWN WAIT ON WEATHER/MAT ~..VA T .TTA'T' T c~ RIG NAME PLATFORM D MIDDLE GROUND SHOAL L=.,~S E PLATFORM "A" WELL A24 - 01LE WORK ORDER 723530 SIDE TRACK DRILLING FOREMAN: SELTZ R H PRESENT ACTIVITY: MAKE UP BHA SWEPI _A.!~3SKA DAILY DRILLING REPORT PAGE 1 OF 1 PROG. D~-H 11943 ELEVAT. KB TO MSL 116. DATE 04/01/95 PRESENT DEPTH 10346 DIST. KB TO BHF 38.4 DAY 10 FOOTAGE DRILLED 116 NLTA LTH/YTD / EST. DAY 22 SIZE OF LAST CSG 7.000 LTA LTH/YTD / DAYS +/- DEP. OF LAST CSG 10888 DAYS SINCE LAST LTA 726 WATER DEPTH 80 LAST BOP TEST 03/31/95 LAST CSG TEST 03/26/95 /FREDERICK DA BHA INSPECTION (CUM. ROT HRS) PP1 ~ KILL SPEED 1650 ~ 30 PP2 @ KILL SPEED 2400 ~ 50 SUMMARY OF OPERATIONS (SHOW HOURS FOR EACH OPERATION) : 4.00 RIH WITH MOTOR ASSY AND BIT ~2 - FILL PIPE ~ 4900' AND 10050' .50 REAM AND WASH 80' TO BOTTOM - ROTATE DRILL FROM 10230' TO 10231' - ORIENT MOTOR 14.50 MOTOR DRILL FROM 10231' TO 10346' - REAM MOTOR RUN 1.00 MWD SURVEY - POOH TO TOW - PUMP DRY JOB 2.50 POOH WITH MOTOR ASSY AND BIT #2 1.50 LAY DOWN BIT #2 A_ND 1.5 DEGREE MOTOR - MAKE UP 1.75 DEGREE MOTOR AND BIT #3 BIT #2 CONDITION: 3-7-BT-H-E-1-JD-BHA TIME (HRS) CUM. ROT. HRS 48.00 ROTATING .50 MUD MOTOR 14.50 TRIPPING 6.50 C&C REAMING SURVEYS 1.00 JET RE PAI RS FISHING NIP UP/DOWN /BOP/W}{ TESTING BOP /WH RUNNING CASING CEMENTING PICKUP/LAY DOWN DS 1.50 INSPECT BHA RIG UP/TEAR DOWN WAIT ON WEATHER/MAT EVALUATION CORING OTHERS SWEPI ALJ~SKA DAILY DRILLING REPORT PAGE 1 OF 1 RIG NAME PLATFORM "A" PROG. DEPTH 11943 9 MIDDLE GROUND SHOAL PRESENT DEPTH 10447 L~SE ' PLATFORM "A" FOOTAGE DRILLED 101 WELL A24-01LE SIZE OF LAST CSG 7.000 WORK ORDER 723530 DEP. OF LAST CSG 10888 SIDE TRACK WATER DEPTH . 80 ELEVAT. KB TO MSL 116.0 DATE 04/02/95 DIST. KB TO BHF 38.4 DAY 11 NLTA LTH/YTD / EST. DAY 22 LTA LTH/YTD / DAYS +/- DAYS SINCE LAST LTA 727 LAST BOP TEST 03/31/95 LAST CSG TEST 03/26/95 DRILLING FOREMAN: SELTZ R H /FREDERICK DA PRESENT ACTIVITY: BHA/MAKE UP CLEAN OUT ASSY SUMMARY OF OPERATIONS (SHOW HOURS FOR EACH OPERATION) : .50 FINISH MAKING UP BHA WITH BIT #3 BHA INSPECTION (CUM. ROT HRS) PP1 % KILL SPEED PP2 @ KILL SPEED 3.00 RIH TO TOW WITH MOTOR ASSY AND BIT #3 - FILL PIPE ~ 5375' AND 9957' 1.00 SLIP AND CUT 100' DRILL LINE .50 CHECK MWD - RIH TO BOTTOM 13.00 ALTERNATE SLIDE, ROTATE AND SURVEY FROM 10346' TO 10447' AFTER DRILLING COAL ~ 10405' - WAS NOT ABLE TO GET WEIGHT ON BIT - REAMED ~ ROTARY DRILLED IN ATTEMPT TO CLEAN UP HOLE - STILL UNABLE TO SLIDE - TRIPPING FOR CLEAN OUT ASSY (LOCKED) .50 CHECK FLOW - PUMP DRY JOB 3.50 POOH WITH 1.75 DEGREE MOTOR AND BIT #3 1.00 BHA - LAY DOWN UP JARS, MWI) AND MOTOR - MAKE UP CLEAN OUT ASSY NOTE: REPORT IS ONLY 23 HRS TO MAKE UP FOR DAYLIGHT SAVINGS TIME NOTE: ESTIMATE $7000 SAVINGS ON THIS WELL BY UTILIZING LEFT-OVER 14.0 PPG MTJD FOR WEIGHTING UP AND DRY JOBS 1300 ~ 30 1950 % 50 TIME (HRS) CUM. ROT. HRS 56.00 ROTATING 1.50 MUD MOTOR 6.50 TRIPPING 7.00 C & C .5O REAMING 2.00 SURVEYS 2.50 JET REPAIRS FISHING NIP UP/DOWN /BOP/WH TESTING BOP /WH RUNNING CASING CEMENTING PICKUP/LAY DOWN DS 2.00 INSPECT BHA RIG UP/TEAR DOWN WAIT ON WEATHER/MAT EVALUATION CORING PLATFORM RIG NAME 9 MIDDLE GROUND SHOAL La.,,~E PLATFORM "A' WELL A24 - 01LE WORK ORDER 723530 SIDE TRACK DRILLING FOREMAN: SELTZ R H PRESENT ACTIVITY: TIH WITH BIT #4 SWEPI/~-'~SKA DAILY DRILLING REPORT PROG. DEPTH 11943 ELEVAT. KB TO MSL PRESENT DEPTH 10449 DIST. KB TO BHF FOOTAGE DRILLED 2 NLTA LTH/YTD SIZE OF LAST CSG 7.000 LTA LTH/YTD DEP. OF LAST CSG 10888 DAYS SINCE LAST LTA WATER DEPTH 80 /FREDERICK DA SUMMARY OF OPERATIONS (SHOW HOURS FOR EACH OPERATION) : 1.00 FINISH MAKING UP CLEAN OUT ASSY WITH BIT #3RR 4.00 RIH TO 10141' - FILL pIpE @ 5372' AND TOW PAGE 1 OF 1 z16. DATE 04/03/95 38.4 DAY 12 - / EST. DAY 22 / DAYS +/- 728 LAST BOP TEST 03/31/95 LAST CSG TEST ~3/26/95 BHA INSPECTION (CUM. ROT HRS) PP1 ~ KILL SPEED 1300 ~ 30 PP2 @ KILL SPEED 1950 @ 50 1.50 WASH A_ND REAM FROM 10141' TO 10447' (DRILLED 2' TO 10449' - 10' FILL) .50 CHECK FLOW - PL-'MP DR~ JOB 2.00 POOH 50 STANDS - CHECK FLOW - WELL FLOWING 2.5 BPH 1.00 RIH TO BOW ~ 10012' - MAKE UP TOP DRIVE 1.50 CLOSE PIPE RAMS, FILL PIPE, CIRC BOTTOMS UP - RETURNS THRU GAS BUSTER 1.50 SHUT IN WELL - MONITOR AND RECORD SHUT IN PRESSURES SIDPP - 30O# SICP - 180# .50 BLEED OFF ANNULUS AND DP PRESSURE - RIH TO 10434' (WGT UP TO 12.0 PPG) 2.50 B~ CIRC - TAG BOTTOM ~ 10449' - CIRC 12.0 PPG KILL MUD AND WORK PIPE SLOWLY - CHECK FLOW - MIX AND PUMP DRY JOB 3.00 POOH WITH BIT #3RR' -' 2.00 LAY DOWN CLEAN OUT ASSY - MAKE UP ADJUSTABLE MOTOR ASSY (1-3/4 DEGREE) AND BIT #4 - ORIENT - SURFACE TEST MWD 3.00 RIH - FILL PIPE ~ 5090' AND TOW TIME (HRS) CUM. ROT. HRS 56.00 ROTATING MUD MOTOR TRIPPING 12.50 C & C 3.O0 REAMING 1.50 SURVEYS JET REPAIRS FISHING NIP UP/DOWN /BOP/WH TESTING BOP /WH RUNNING CASING CEMENTING PICKUP/LAY DOWN DS 3.00 INSPECT BHA RIG UP/TEAR DOWN WAIT ON WEATHER/MAT EVALUATION CORING OTHERS 4.00 NOTE: PRIOR TO WEIGHTING UP - BOTTOMS UP GAS WAS 50 % LEL SWEPI ALASKA DAILY DRILLING REPORT IAME PLATFORM 'A" 11943 ~-_~D MIDDLE GROUND SHOAL 10497 LEASE PLATFORM 'A" 48 WELL A24-01LE 7.000-' WORK ORDER 723530 10888 SIDE TRACK ~ 80 DRILLING FOREMAN: SELTZ R H - /FREDERICK DA PRESENT ACTIVITY: MOTOR DRILLING SUMMARY OF OPERATIONS (SHOW HOURS FOR EACH OPERATION) : 1.00 FINISH TIH .50 BREAK CIRC - ORIENT MOTOR PROG. DEPTH PRESENT DEPTH FOOTAGE DRILLED SIZE OF LAST CSG DEP. OF LAST CSG WATER DEPTH 8.00 DRLG. W/MOTOR FROM 10,449' TO 10,472' PAGE 1 OF 1 ELEVAT. KB TO MSL 116.0 DATE .94/04/95 DIST. KB TO BHF 38.4 DAY 13 NLTA LTH/YTD / EST. DAY 22 LTA LTH/YTD / DAYS DAYS SINCE LAST LTA 729 LAST BOP TEST 03/31/95 LAST CSG TEST 03/26/95 BHA INSPECTION (CUM. ROT HRS) PP1 @ KILL SPEED 1250 ~ 30 PP2 @ KILL SPEED 2025 @ 50 NOTE; MOTOR WAS JETTED W/SIZE 13 NOZZLE - DUE TO PUMP PRESSURE LIMITATIONS, COULD NOT PUMP ENOUGH GPM'S TO GET PROPER HP TO BIT - MOTOR KEPT STALLING - WILL TOOH TO CHANGE 13 NOZZLE TO BLANK. AFTER TIH & DRILLING, HOLE STARTED TAKING FLUID (67 SPM) REDUCED SPM TO 60 & LOSS STOPPED - LAST COUPLE HRS OF DRILLIN~ INCREASED STROKES TO 67 WITH NO LOSS. .50 TOOH TO 10,100' - NO PROBLEMS .50 DROP BAR & SHEAR P/O SUB - pump DRY JOB 3.00 TOOH FOR MOTOR 2.00 BI-IA - CHANGE NOZZLE IN MOTOR - CIiANGE BIT - TEST MWD 3.50 TIM W/1.75 DEG MOTOR & BIT ~5 - FILL PIPE ~ 5090' CUT DRLG LINE .50 TIH - FILL PIPE - TEST MWD ~.5~ BREAK CIRC. - REAM 30' TO BOTTOM - MOTOR DRILL FROM 10,472' TO 10,497' IADC DULL GRADE BIT #4 - 2-4-CT-H-E-I-WT-BHA TIME (HRS) CUM. ROT. HRS 68.00 ROTATING MUD MOTOR 12.00 TRIPPING 8.50 _ C & C .5O REA/WING SURVEYS JET REPAIRS FISHING NIP UP/DOWN /BOP/WH TESTING BOP /WH RUNNING CASING CEMENTING PICKUP/LAY DOWN DS 2.00 INSPECT BHA RIG UP/TEAR DOWN WAIT ON WEATHER/MAT EVALUATION CORING SWEPI~'--~kSKA DAILY DRIIJ~ING REPORT RIG NAME PLATFORM "A' PROG. DEPTH 11943 ' D MIDDLE GROU1TD SHOAL PRESENT DEPTH 10578 L .E PLATFORM 'A" FOOTAGE DRILLED 81 WELL A24-01LE SIZE OF LAST CSG 7.000 WORK ORDER 723530 DEP. OF LAST CSG 10888 SIDE TRACK WATER DEPTH 80 DRILLING FO~: SELTZ R H /GALLOWAY DR PRESENT ACTIVITY: FILL DP AT WINDOW AND RIH SUMMARY OF OPERATIONS (SHOW HOURS FOR EACH OPERATION) : 14.50 MOTOR DRILL FROM 10,497 TO 10,578 (81'). PAGE 1 OF 1 ELEVAT. KB TO MSL 116.. DATE 04/05/95 DIST. KB TO BHF 38.4 DAY 14 NLTA LTH/YTD __/ EST. DAY 22 LTA LTH/YTD / DAYS +/- DAYS SINCE LAST LTA 730 LAST BOP TEST 0.3/31/95 LAST CSG TEST 03/26/95 BHA INSPECTION (CUM. ROT HRS) PP1 ~ KILL SPEED 1325 ~ 30 PP2 · KILL SPEED 1950 % 50 NOTE~ STILL EXPERIANCING SOME MOTOR PROBLEMS WITH STALLING. LOST 30 BBL MUD TO FORMATION. LOSSES STOPPED DURING LAST 3 HOURS OF DRILL TIME. FORMATIO~ APPEARED TO HAVE HEALED UP. .50 CHECK FOR FLOW AND POH WITH 6 STDS OF DRILLPIPE. .50 SPOT 25 BBL LOWATE PREMIX PILL FROM 9700' TO 9200' TO HELP CONTROL LOSSES. 1.00 POH TO 9075'. SHEAR PUMP OUT SUB AND PUMP DRY JOB. 3.00 POH WITH BIT #5. .50 LAID DOWN BHA AND BIT #5. 1.00 M/U BIT #6 - PICKED UP NEW 1.75 DEG MOTOR. ORIENT AND SURFACE TEST MTR 3.00 RIH WITH BHA - FILL DP AT 5090' AND AT WINDOW. IADC DULL GRADE BIT- ~5 - 3-8-BT-H-E-4-RG-HRS/PR NOTE; DAILY COST HIGH DUE TO 7/8 WIREROPE PURCHASE FOR $3M AND ROTELLA MOTOR OIL PURCHASE OF $5.5M. TIME (HRS) CUM. ROT. HRS 81.00 ROTATING 1.00 MUD MOTOR 12.00 TRIPPING 7.00 C & C 1.00 REAMING .50 SURVEYS 1. O0 JET REPAIRS FISHING NIP UP/DOWN /BOP/WH TESTING BOP /WH RUNNING CASING CEMENTING PICKUP/LAY DOWN DS INSPECT BHA RIG UP/TEAR DOWN 1.50 WAIT ON WEATHER/MAT EVALUAT I ON CORING OTHERS SWEPI AIJuSKA DAILY DRILLING REPORT PAGE 1 OF 1 Rm' NAME PLATFORM "Am PROG. DEPTH 11943 i J MIDDLE GROUND SHOAL PRESENT DEPTH 10690 LEASE PLATFORM 'A" FOOTAGE DRILLED 112 WELL A24-01LE SIZE OF LAST CSG 7.000 WORK ORDER 723530 DEP. OF LAST CSG 10013 SIDE TRACK WATER DEPTH 80 ELEVAT. KB TO MSL 116.0 DATE 04/06/95 DIST. KB TO BHF 38.4 DAY 15 NLTA LTH/YTD / EST. DAY 22 LTA LTH/YTD / DAYS +/- DAYS SINCE LAST LTA 731 LAST BOP TEST 03/31/95 LAST CSG TEST 03/26/95 PRESENT ACTIVITY: MOTOR DRILLING /GALLOWAY 'DR BHA INSPECTION (CUM. ROT HRS) PPl ~ KILL SPEED PP2 ~ KILL SPEED SUMMARY OF OPERATIONS (SHOW HOURS FOR EACH OPERATION) : 1.00 CONTINIIE TO RIH WITH BHA TO 10,500. BREAK CIRCULATION ~ REAMED OUT OPEN HOLE FROM 10,500 TO 10,578' (APPROX 15' UNDERGAUGE). 13.00 ORIENT MOTOR AND MOTOR DRILL FROM 10 578' TO 10,686' WITH MINIMUM MUD LOSSES. 1.00 CHECK FLOW DROP S~EAR BAR, AND PUMP DRY JOB. 3.00 POH WITH BIT #6. 1.50 LAY DOWN BHA A/STD M/U SAME B~IA WITH BIT #7. SURFACE TEST MOTOR. 3.00 RIH WITH BHA. FILL PIPE AT 5090' AND WINDOW. 1.50 TAGGED UP AT 10,686'. BREAK CIRCUIJkTION AND MOTOR DRILL FROM 10686' TO 10,690'. IADC BIT GRADE #6 - 2-5-CT-MH-E-I-RG-BHA-BIT WAS PULLED DUE TO SURFACE INDICATIONS OF ROUNDED GAUGE. NOTE; CORRECT DAILY ~dD COSTS $7452 A_N'D CORRECT DAILY COSTS $37,102. INCORRECT ENTRIES MADE TO REPAIR MISTAKE MADE BY DOC SOFTWARE. . 1020 @ 30 2450 ~ 50 TIME (HRS) CUM. ROT. HRS 94.50 ROTATING 3.00 MUD MOTOR 10.50 TRIPPING 6.00 C & C 1.00 REAMING 1. O0 SURVEYS 1.00 JET REPAIRS FISHING NIP UP/DOWN /BOP/WH TESTING BOP /WH RUNNING CASING CEMENTING PICKUP/LAY DOWN DS INSPECT BHA RIG UP/TEAR DOWN 1.50 WAIT ON WEATHER/MAT EVALUATION CORING SWEPI ~--~-'qKA DAILY DRILLING REPORT Rim NAME PLATFORM "A" PROG. DEPTH 11943 ELEVAT. KB TO MSL ! MIDDLE GROUND SHOAL PRESENT DEPTH 10862 DIST. KB TO BHF LEASE PLATFORM "A' FOOTAGE DRILLED 172 NLTA LTH/YTD WELL A24-01LE SIZE OF LAST CSG 7.000 LTA LTH/YTD WORK ORDER 723530 DEP. OF LA. ST CSG 10013 DAYS SINCE LAST LTA SIDE TRACK WATER DEPTH 80 DRILLING FO~: SELTZ R H /GALLOWAY DR PRESENT ACTIVITY: TESTING BOP 116. ~ l DATE 38.4 DAY PAGE 1 OF 1 o4/o7/~s 16 / EST. DAY 22 . / DAYS +/- 732 , _ ~T BOP TEST 03/31/95 LAST CSG TEST 03/26/95 BNA INSPECTION (CUM. ROT HRS) PP1 ® KILL SPEED 1020 ~ 30 PP2 ~ KILL SPEED 2450 ~ 50 S~Y OF OPERATIONS (SHOW HOURS FOR EAC~ OPERATION) : 16.50 MOTOR DRILLED FROM 10690' TO 10862' WITH MINIMUM MUD LOSSES. 1.00 CHECK FOR FLOW~ DROP DART, AND PUMP DRY JOB. 3.00 POH WITH BHA. .50 CHECK MWD AND LSD BNA.' 3.00 PERFORM WEEKLY BOP TEST. NOTE: NOTIFIED BLAIR WITH AOGC AT 7:40 A.M. ON 4/6/95 OF UPCOMING WEEKLY BOP TEST. AOGC DECLINED TO WITNESS TESTING. IADC DULL GRADE BIT #7 - 2-3-BT-H-E-I-LT/ER-HRS NOTE: CORRECT DAILY COSTS OF $30,052. INCORRECT NI3M~ER ENTERED DUE TO PROBLEM WITH DOC SOFTWARE. CUM. COSTS ARE CORRECT'. TIME (HRS) CUM. ROT. HRS 109.00 ROTATING 1.00 MUD MOTOR 13.50 TRIPPING 3.00 C&C 1.00 REAMING SURVEYS 2.00 JET REPAIRS FISHING NIP UP/DOWN /BOP/WH TESTING BOP /WH 3.00 RUNNING CASING CEMENTING PICKUP/LAY DOWN DS INSPECT BNA RIG UP/TEAR DOWN .50 WAIT ON WEATHER/MAT EVALUAT I ON CORING OTHERS SWEPI ALASKA DAILY DRILLING REPORT PAGE 1 OF 1 Rim NAME PLATFORM "A" PROG. DEPTH 11943 } MIDDLE GROUND SHOAL PRESENT DEPTH 11025 LEASE PLATFORM 'A" FOOTAGE DRILLED 163 WELL A24-01LE SIZE OF LAST CSG 7.000 WORK ORDER 723530 DEP. OF LAST CSG 10013' SIDE TRACK WATER DEPTH 80 ELEVAT. KB TO MSL 116.0 DATE Q4/08/95 DIST. KB TO BHF 38.4 DAY 17 NLTA LTH/YTD / EST. DAY 22 LTA LTH/YTD / DAYS +/- DAYS SINCE LAST LTA 733 LAST BOP TEST 04/07/95 LAST CSG TEST 03/26/95 DRILLING FOREMAR: SELTZ R H /GALLOWAY DR PRESENT ACTIVITY: MOTOR DRILLING SUMMARY OF OPERATIONS (SHOW HOURS FOR EACH OPERATION) : 1.50 COMPLETE SUCCESSFULL WEEKLY BOP TESTS. .50 M/U BNA WITH BIT #8. SURFACE TEST MWD. 3.50 RIH WITH BHA. FILL PIPE AND TEST MWD AT 5090 AND WINDOW. 1.00 BRF, AK CIRCULATION AND REAM OPEN HOLE FROM 10620 TO 10862'. !7.50 MOTOR DRILLING FROM 10862' TO 11025' WITH MINIMUM MUD LOSSES. DRILLING AHEAD AT REPORT TIME. BNA INSPECTION (CUM. ROT HRS) PP1 ~ KILL SPEED PP2 ~ KILL SPEED 1280 @ 30 1980 ~ 50 TIME (HRS) CUM. ROT. HRS 125.50 ROTATING 1 . 00 MUD MOTOR 15.50 TRIPPING 3.50 C & C REAM I NG 1.00 SURVEYS 1.00 JET REPAIRS FISHING N~P UP/DOWN /BOP/WH TESTING BOP /WH 1.50 RUNNING CASING CEMENTING PICKUP/LAY DOWN DS INSPECT BNA RIG UP/TEAR DOWN .50 WAIT ON WEATHER/MAT EVALUAT I ON CORING R'' NAME PLATFORM 'A" ~ MIDDLE GROUND SHOAL LEASE PLATFORM "A" WELL A24 - 01LE WORK ORDER 723530 SIDE TRACK DRILLING FOREMAN: SELTZ R H PRESENT ACTIVITY: ROTARY DRILLING SWEPI AL~S~KA DAILY DRILLING REPORT PROG. DEPTH 11943 PRESENT DEPTH 11078 FOOTAGE DRILLED 53 SIZE OF LAST CSG 7.000 DEP. OF LAST CSG 10013 WATER DEPTH 80 /GALLOWAY DR S~Y OF OPERATIONS (SHOW HOURS FOR EACH OPERATION) : 4.50 MOTOR DRILL FROM 10,954 TO 11,048' PAGE 1 OF 1 ELEVAT. KB TO MSL 116.I DATE DIST. KB TO BHF 38.4 DAY NLTA LTH/YTD /__ EST. DaY LTA LTH/YTD /__ DAYS +/- DAYS SINCE LAST LTA 734 04/09/95 18 22 LAST BOP TEST 04/07/95 LAST CSG TEST 03/26/95 BHA INSPECTION (CUM. ROT HRS) PPl % KILL SPEED 1050 ~ 30 PP2 · KILL SPEED 1900 ~ 50 1.00 CHECK FLOW, PULL TO WINDOW, DROP SHEAR BAR AND PUMP DRY JOB. 4.50 POH WITH BHA ~8. 2.00 L/D BHA AND M/U BHA WITH BIT #9. 4.50 RIH WITH BHA TO 9953'. STOPPED AND ADJUSTED BRAKES AND SLIP 100' OF' DRILL LINE. FILLED PIPE AT 4900 AND 9953'. 1.00 SERVICE TOP DRIVE, DRAWWORKS, A_ND AR-3000. .50 RIH WITH BHA TO 10,430'. 2.00 B~ CIRCULATION AND RF_JtMED OPEN HOLE FROM 10,430' TO 11,048'. 4.00 ROTARY DRILL FROM 11048 TO 11,078' NOTE: "NO' PUMP OUT SUB IN BNA. . IADC DULL GRADE BIT #8 7-8-L/T-H-E-I-ER-PR/HRS _ TIME (HRS) CUM. ROT. HRS 133.00 ROTATING 5.00 MUD MOTOR 2.50 TRIPPING 9.00 C & C 1.00 REAMING 2.50 SURVEYS 1.00 JET REPAIRS FISHING NIP UP/DOWN /BOP/WH TESTING BOP /WH RUNNING CASING CEMENTING PICKUP/LAY DOWN DS INSPECT BNA RIG UP/TEAR DOWN 2.00 WAIT ON WEATHER/MAT EVALUAT I ON CORING OTHERS 1.00 . __ SWEPI ALASKA DAILY DRILLING REPORT PAGE 1 OF 1 R~' "AME PLATFORM 'A' PROG. DEPTH 11943 F MIDDLE GROUND SHOAL PRESENT DEPTH 11179 LEASE PLATFORM 'A" FOOTAGE DRILLED 101 WELL A24-01LE SIZE OF LAST CSG 7.000 WORK ORDER 723530 DEP. OF LAST CSG 10013 SIDE TRACK WATER DEPTH 80 ELEVAT. KB TO MSL 116.0 DATE 04/10/95 DIST. KB TO BHF 38.4 DAY 19 NLTA LTH/YTD / EST. DAY 22 LTA LTH/YTD / DAYS +/- DAYS SINCE LAST LTA 735 LAST BOP TEST 04/07/95 LAST CSG TEST 03/26/95 DRILLING FOREMAN: SELTZ R H PRESENT ACTIVITY: ROTARY DRILLING /GALLOWAY DR gUMmY OF OPERATIONS (SHOW HOURS FOR EACH OPERATION) : 8.50 ROTARY DRILLING FROM 11078 TO 11138'. .50 CHECK FLOW AND PUMP DRY JOB. 4.00 POH wITH BIT ~9 AND BHA. 1.00 CHECK MWD, GAUGE ALL STABILIZERS, AND M/U BIT #10. 4.00 SURFACE TEST MWD, RIH WITH BNA. FILL DP AT 4900' A/qD WINDOW. .50 BROKE CIRCULATION AT 11088' AND REAMED TO 11138'. 5.50 ROTARY DRILL FROM 11,138' TO 11,179'. NOTE: IADC DULL GRADE BIT #9 - 7-8-RG-H-E-1/2-RG/SD-PR BNA INSPECTION (CUM. ROT HRS) PP1 ~ KILL SPEED PP2 ~ KILL SPEED 1100 ~ 30 1600 ~ 50 TIME (HRS) CUM. ROT. HRS 147.00 ROTATING 14.00 MUD MOTOR TRIPPING 6.00 C & C 1.50 REAMING .50 SURVEYS JET REPAIRS FISHING NIP UP/DOWN /BOP/WH TESTING BOP /WH RUNNING CASING CEMENTING PICKUP/LAY DOWN DS INSPECT BNA RIG UP/TEAR DOWN 2.00 WAIT ON WEATHER/MAT EVALUATION CORING SWEP. 3%SKA DAILY DRILLING REPORT ! JU~E PLATFORM "A~ FIELD MIDDLE GROUND SHOAL LF. ASE PLATFORM "Aw WELL A24-01LE WORK ORDER 723530 SIDE TRACK DRILLING FOREMAN: SELTZ R H PRESENT ACTIVITY: ROTARY DRILLING PROG. DEPTH 11943 ELEVAT. KB TO MSL PRESENT DEPTH 11270 DIST. KB TO BHF FOOTAGE DRILLED 91 NLTA LTH/YTD SIZE OF LAST CSG 7.000 LTA LTH/YTD DEP. OF LAST CSG 10013 DAYS SINCE LAST LTA WATER DEPTH 80 /GALLOWAY DR SUMMARY OF OPERATIONS (SHOW HOURS FOR EACH OPERATION) : 4.00 ROTARY DRILL FROM 11179' TO 11,205'. .50 CHECK FOR FLOW ~ PUMP DRY JOB. 4.00 POH WITH BHA. 1.00 L/D BHA AND M/U BIT #11 WITH SAME BHA DESIGN. 4.00 RIH WITH BHA. FILLED PIPE AT 4900 AND WINDOW. -" PAGE 1 OF 1 116.0 DATE 04/11/95 38.4 DAY 20 · /__ EST. DAY 22 /__ DAYS 736 __ LAST BOP TEST 04/07/95 LAST CSG TEST 03/26/95 BHA INSPECTION (CUM. ROT HRS) PP1 ~ KILL SPEED 1100 ~ 30 PP2 ~ KILL SPEED 1660 % 50 1.00 WORKED OUT OF TIGHT HOLE AT 11185'. BROKE CIRCUIJ~TION AND REAMED HOLE FROM 11~155' TO 11~205'. TIGHT HOLE FROM 11185-11205'. 9.50 ROTARY DRILL FROM 11~205' TO 11,270'. NOTE: IADC DULL BIT GRA/)E BIT #10 - 4-7-BT-H3-E-5/16-RG-TQ TIME (HRS) CUM. ROT. HRS 160.50 ROTATING 13.50 MUD MOTOR TRIPPING 8.00 C & C .5O REAMING 1.00 SURVEYS JET REPAIRS FISHING NIP UP/DOWN /BOP/WH TESTING BOP /WH RUNNING CASING CEMENTING PICkUP/LAY DOWN DS INSPECT BHA RIG UP/TEAR DOWN 1.00 WAIT ON WEATHER/MAT EVALUATION CORING SWEPI ALASKA DAILY DRILLING REPORT PAGE 1 OF 1 RIG NAME PLATFORM "A" PROG. DEPTH 11943 F~ % MIDDLE GROUND SHOAL PRESENT DEPTH 11372 L PLATFORM "A" FOOTAGE DRILLED 102 WELL A24-01LE ' SIZE OF LAST CSG 7.000 WORK ORDER 723530 DEP. OF LAST CSG 10013 SIDE TRACK WATER DE~TH 80 ELEVAT. KB TO MSL 116.0 DATE 04/12/95 DIST. KB TO BHF 38.4 DAY 21 NLTA LTH/YTD / EST. DAY 22 LTA LTH/YTD / DAYS +/- DAYS SINCE LAST LTA 737 LAST BOP TEST 04/07/95 LAST CSG TEST 03/26/95 DRILLING FOREMAN: WELLS R V PRESENT ACTIVITY: ROTARY DRILLING /GALLOWAY DR BHA INSPECTION (CUM. ROT HRS) PPi @ KILL SPEED PP2 ~ KILL SPEED SUMMARY OF OPERATIONS (SHOW HOURS FOR EACH OPERATION) : 10.50 ROTARY DRILL FROM 11,270' TO 11,345' - DRILLING BREAK AT 11,342' AND SIGNS OF COAL UPON CIR~TING BOTTOMS UP. .50 CHECK FLOW AND PUMP DRY JOB. 3.50 POH WITH BHA. · 50 L/D BIT #11 BHA A_ND M/U BIT #12. DID NOT RERUN MWI) ORIENT SUB. 4.50 RIH WITH BHA. FILL DP AT 4900' AND WINDOW. 1.00 BREAK CIR~TION AND REAMED 70' DOWN TO BOTTOM. 3.50 ROTARY DRILL FROM 11,345' TO 11,372'. NOTE: IACD DULL BIT GRADE BIT ~11 - 5-6-BT-HM-F-1/16-JD/ER-HRS NOTE: LOST 12 BBLS OF MUD IN LAST 3 HOURS OF DRILLING. ADDED CALCIUM CARBONATE TO MUD SYSTEM AND REDUCED CIRCULATION GPM FROM 176 GPM TO 150 GPM. RUNNING CENTRIFUGE TO REDUCE MUD WEIGHT. NO MUD LOSS AT THIS UNDER THESE NEW PARAMETERS. 1120 ~ 30 1550 ~ 50 TIME (HRS) CUM. ROT. HRS 174.50 ROTATING 14 . 00 FFUD MOTOR TRIPPING 8 . 00 C & C 1.00 REAMING .50 SURVEYS JET REPAIRS FISHING NIP UP/DOWN /BOP/WH TESTING BOP /WH RUNNING CASING CEMENTING PICKUP/LAY DOWN DS INSPECT BHA RIG UP/TEAR DOWN .50 SWEPI~-~KADAILY DRILLING REPORT RIG NAME PLATFORM "A" PROG. DEPTH 11943 D MIDDLE GROUND SHOAL PRESENT DEPTH 11480 L~.,~SE PLATFORM "A" FOOTAGE DRILLED 108 WELL A24-01LE SIZE OF LAST CSG 7.000 WORK ORDER 723530 DEP. OF LAST CSG 10013 SIDE TRACK WATER DEPTH 80 DRILLING FOREMAN: WELLS R V /GALLOWAY DR PRESENT ACTIVITY: FILLING PIPE AT THE WINDOW, 10000' SUMMARY OF OPERATIONS (SHOW HOURS FOR EACH OPERATION) : 15.50 ROTARY DRILL F/11372' T/11480' W/BIT ~12. 1.00 DROP/PUMP DUAL SINGLE SHOT SURVEY TOOLS. PAGE 1 OF 1 ELEVAT. KB TO MSL 116. DATE 04/13/95 DIST. KB TO BHF 38.4 DAY 22 NLTA LTH/YTD / EST. DAY 22 LTA LTH/YTD / DAYS +/- DAYS SINCE LAST LTA 738 LAST BOP TEST 04/07/95 LAST CSG TEST 03/26/95 BF~A INSPECTION (CUM. ROT HRS) PP1 % KILL SPEED 1120 ~ 30 PP2 ~ KILL SPEED 1550 ® 50 7.50 POH W/BIT ~12, RECOVERED SS SURVEYS. CHANGED BITS, PUT A JOINT OF HWDP BETWEEN THE JARS. TI~ T/4928', FILL PIPE, TIH T/WINDOW AT 10000' AND FILLING PIPE THERE AT REPORT TIME. BIT ~12 COND: 4-4-BT-MH-E-I-LT/ER HRS FIRE DRILL AT 1405 HRS, WELL SECURED IN 1 MINUTE. NO ACTUAL FIRE. . _ TIME (HRS) CUM. ROT. HRS ROTATING MUD MOTOR TRIPPING C & C REAMING SURVEYS JET REPAIRS FISHING NIP UP/DOWN /BOP/WH TESTING BOP /WH RUNNING CASING CEMENTING PICKUP/LAY DOWN DS INSPECT BHA RIG UP/TEAR DOWN WAIT ON WEATHER/MAT EVALUATION CORING OTHERS 190.00 15.50 7.50 1.00 SWEPI ALASKA DAILY DRILLING REPORT PAGE 1 OF 1 RI ~- --NAME PLATFORM "A" Fi MIDDLE GROUND SHOAL LE~,~ E PLATFORM "A" WELL A24-OILE WORK ORDER 723530 SIDE TRACK DRILLING FOREMAN: %JELLS R V PRESENT ACTIVITY: ROTARY DRILLING PROG. DEPTH 1-1943 PRESENT DEPTH 11655 ~OOTAGE DRILLED 175 SIZE OF LAST CSG 7.000 DEP. OF LAST CSG 10013 WATER DEPTH 80 /GALLOWAY DR SUMMARY OF OPERATIONS (SHOW HOURS FOR EACH OPERATION) : .5O ELEVAT. KB TO MSL 116.0 DATE ~4.~!E/9~ DIST. KB TO BHF 38.4 DAY 23 NLTA LTH/YTD / EST. DAY 22 LTA LTH/YTD ___/___ DAYS +/- DAYS SINCE LAST LTA 739 LAST BOP TEST ~4/~Z/9~ LAST CSG TEST ~3/[~/9~ BHA INSPECTION (CUM. ROT HRS) PP1 @ KILL SPEED 1100 @ 30 PP2 @ KILL SPEED 1560 @ 50 23.50 -- CONT TO RIH FROM WINDOW BREAK CIRCULATION AT 11,400 AND REAMED ~O__~g~ T__O 1_~L480 - TIGHT HOLE AT~ 44z~7 A~D 11,4__7~.__ .......... ROTARY DRILLED-FROM 11,480' TO 11~655~ TIME iH. RS) CUM. ROT. HRS ROTATING MUD MOTOR TRIPPING C & C REAMING SURVEYS JET REPAI RS FISHING NIP UP/DOWN /BOP/UH TESTING BOP /WH RUNNING CASING CEMENTING PICKUP/LAY DOWN DS INSPECT BNA RIG UP/TEAR DO%JN gAIT ON WEATHER/MAT EVALUATION CORING OTHERS 213.50 23.50 .50 SWEPI '~--~KA DAILY DRILLING REPORT P"~ NAME PLATFORM "A~ D MIDDLE GROUND SHOAL LEASE PLATFORM "A~ WELL A24 - 01LE WORK ORDER 723530 SIDE TRACK DRILLING FOREMAN: WELLS R V PRESENT ACTIVITY: ROTARY DRILLING PROG. DEPTH 11943 PRESENT DEPTH 11665 FOOTAGE DRILLED 10 SIZE OF LAST CSG 7.000 DEP. OF LAST CSG 10013 WATER DEPTH 80 /GALLOWAY DR SUMMARY OF OPERATIONS (SHOW HOURS FOR EACH OPERATION) : 1.00 ROTARY DRILL FROM 11,655 TO 11,665'. 1.00 DROP SINGLE SHOT SURVEY, CHECK FLOW, AND PUMP DRY JOB. PAGE 1 OF 1 ELEVAT. KB TO MSL l16.u. DATE 04/15/95 DIST. KB TO BHF 38.4 DAY 24 NLTA LTH/YTD / EST. DAY 22 LTA LTH/YTD __/ DAYS +/- DAYS SINCE LAST LTA 740 ... LAST BOP TEST 04/14/95 LAST CSG TEST 03/26/95 BHA INSPECTION (CUM. ROT HRS) PP1 ~ KILL SPEED 1560 ~ 30 PP2 ~ KILL SPEED 2450 ~ 50 4.00 POH WITH BHA - LAID DOWN 30 JTS DRILLPIPE TO SEND IN FOR INSPECTION. 4.00 PERFORM WEEKLY'BOP TEST o BOBBY FOSTER OF AOGC ON LOCATIO TO WITNESS TESTS. 3.50 L/D N/M BHA AND M/U NEW STEEL BHA WITH BIT ~14. 4.00 RIH WITH BHA. FILL DP AT 5000' AND WINDOW. 2.00 SERVICE TOP DRIVE, SLIP 100' DRILL LINE, ~ SERVICE RIG. .50 CONT. TO RIH WITH BHA. TAGGED UP ON TIGHT HOLE AT 11,261. 3.50 BREAK CIRCULATION AND REAMED TIGHT HOLE FROM 11,261' TO 11,655'. .50 ROTARY DRILL FROM 11,655' TO 11,665'. NOTE - IADC DULL BIT GRADE BIT #13 - 7-8-BT-I'IM-F-1/8~ID/ER-HRS . TIME (HRS) CUM. ROT. HRS 215.00 ROTAT I NG 1 . 50 MUD MOTOR TRIPPING 8 . 50 C&C REAMING 3.5O SURVEYS 1.00 JET REPAIRS 2.00 FISHING NIP UP/DOWN /BOP/WH TESTING BOP /WH 4.00 RUNNING CASING CEMENTING PICkUP/LAY DOWN DS INSPECT BNA 3.50 RIG UP/TEAR DOWN WAIT ON WEATHER/MAT EVALUAT I ON CORING OTHERS SWEPI ALASKA DAILY DRILLING REPORT PAGE 1 OF 1 NAME PLATFORM "A' PROG. DEPTH 11943 ~D MIDDLE GROUND SHOAL PRESENT DEPTH 11849 ~EASE PLATFORM 'A" FOOTAGE DRILLED 184 {ELL A24-01LE SIZE OF LAST CSG 7.000 {ORK ORDER 723530 DEP. OF LAST CSG 10013 ~IDE TRACK WATER DEPTH 80 ELEVAT. KB TO MSL 116.0 DATE 04/16/95 DIST. KB TO BHF 38.4 DAY 25 NLTA LTH/YTD / EST. DAY 22 LTA LTH/YTD / DAYS +/- DAYS SINCE LAST LTA 741 LAST BOP TEST 04/14/95 LAST CSG TEST 03/26/95 )RILLING FOREMAN: WELLS R V ?RESENT ACTIVITY: M/U BNA /GALLOWAy DR ~UMMARY OF OPERATIONS (SHOW HOURS FOR EACH OPERATION) : .9.00 ROTARY DRILL FROM 11,665' TO 11,849'. .50 CHECK FLOW AND PUMP DRY JOB. 3.50 POH WITH BHA. 1.00 L/D BHA. NOTE: IADC DULL BIT GRADE BIT ~14 - 5-8-BT-A-E-1/2-CT-TQ NOTE: CORRECTION TO DEPTH IN WITH BIT #14; CORRECT DEPTH IN 11,662'. BHA INSPECTION (CUM. ROT HRS) PP1 % KILL SPEED PP2 @ KILL SPEED 1140 ~ 30 1580 ~ 50 TIME (HRS) CUM. ROT. HRS ROTATING MUD MOTOR TRIPPING C & C REAMING SURVEYS JET REPAIRS FISHING NIP UP/DOWN /BOP/WH TESTING BOP /WH RUNNING CASING CEMENTING PICKUP/LAY DOWN DS INSPECT BHA RIG UP/TEAR DOWN WAIT ON WEATHER/MAT EVALUATION CORING 234.00 19.00 3.50 .50 1.00 SWEPI k ~K.A DAILY DRILLING REPORT RY" NAME PLATFORM "A" PROG. DEPTH 11943 F MIDDLE GROUND SHOAL PRESENI DEPTH 12000 LEASE PLATFORM "A" FOOTAGE DRILLED 151 WELL A24-01LE SIZE OF LAST CSG 7.000 WORK ORDER 723530 DEP. OF LAST CSG 10013 ~IDE TRACK WATER DEPTH 80 DRILLING FOREMAN: WELLS R V PRESENT ACTIVITY: SERVICING RIG /GALLOWAY DR ~UMMARY OF OPERATIONS (SHOW HOURS FOR EACH OPERATION) : 1.00 M/U BHA WITH BIT #15. PAGE 1 OF 1 ELEVAT. KB TO MSL 116.0 DATE 04/17/95 DIST. KB TO BHF 38.4 DAY 26 NLTA LTH/YTD / EST. DAY 22 -- LTA LTH/YTD / DAYS +/- DAYS SINCE LAST LTA 742 -- I_J~ST BOP TEST 04/14/95 LAST CSG TEST 03/26/95 BHA INSPECTION (CUM. ROT HRS) PP1 · KILL SPEED 1210 ~ 30 PP2 ~ KILL SPEED 1500 ~ 50 4.00 RIH WITH BHA TO 11,814'. FILL DP AT 5650 AND WINDOW. .50 BREAK CIRCULATION AND REAM OPEN HOLE FROM 11,814' TO 11,849'. !6.00 ROTARY DRILL FROM 11,849' TO 12,000'. 1.00 CIRCULJ%TE BOTTOMS UP WHILE WORKING DP. 1.00 CHECK FOR FLOW AND POH WITH DP TO WINDOW FOR SHORT TRIP. SWEPI ALASKA DAILY DRILLING REPORT .50 SERVICING RIG AT REPORT TIME. NOTE: "HC" COAL BETWEEN MD 11,902' TO 11,915'. TIME (HRS) CUM. ROT. HRS 250.00 ROTATING 16 . 00 M-U-D MOTOR TRIPPING 5.00 C &C 1.00 REAMING .50 SURVEYS JET RE PAI RS FISHING NIP UP/DOWN /BOP/WH TESTING BOP RUNNING CASING CEMENTING PICKUP/LAY DOWN DS INSPECT BHA 1.00 RIG UP/TEAR DOWN WAIT ON WEATHER/MAT EVALUAT I ON CORING OTHERS .50 PAGE 1 OF 1 RT' NAME PLATFORM "A" PROG. DEPTH 11943 ~ , MIDDLE GROUND SHOAL PRESENT DEPTH 11994 LEASE PLATFORM "A~ FOOTAGE DRILLED WELL A24-01LE SIZE OF LAST CSG 7.000 WORK ORDER 723530 DEP. OF LAST CSG 10013 SIDE TRACK WATER DEPTH 80 ELEVAT. KB TO MSL 116.0 DATE 04/18/95 DIST. KB TO BHF 38.4 DAY 27 NLTA LTH/YTD / EST. DAY 22 LTA LTH/YTD / DAYS +/- DAYS SINCE LAST LTA 743 LAST BOP TEST 04/14/95 LAST CSG TEST 03/26/95 DRILLING FOREMAN: WELLS R V PRESENT ACTIVITY: POH W/WIRELINE /FREDERICK DA SUMMARY OF OPERATIONS (SHOW HOURS FOR EACH OPERATION) : .50 FINISHED SERVICE RIG WHILE AT THE WINDOW. 1.00 TIH T/BOTTOM, 12,000'. BHA INSPECTION (CUM. ROT HRS) PPI · KILL SPEED PP2 % KILL SPEED 4.50 CIRC/COND FOR LOGS. PUMPED AROUND RICE AND PAINT TO DETERMINE OPEN HOLE SIZE WHILE CIRC. RESULTS WERE INCONCLUSIVE. PUMPED AT 226 GPM. 5.50 SLM OUT OF HOLE. NOTE A'6' coRRECTiON TO T.D2 NOW 11994'. 1.50 PICKED UP DRILL PIPE CONVEYED LOGGING TOOLS; DITE/AIT/BHC/LDT/CNL/GR. MAKE UP WIRELINE AND DOCKING SUB, CHECKED CALIBRATION. HELD SAFETY MEETING ABOUT OPERATION/PROCEDURES OF RUNNING DRILL PIPE AND WIRELINE SIMULTANEOUSLY ETC. 5.50 TIH W/TOOLS T/9284', FILLED PIPE EACH 10 STANDS. 1.50 MADE UP SIDE ENTRY SUB. RIG UP SCHLUMBERGER SHEAVES/LINE. (HAD CREW CHANGE) HELD SAFETY MEETING W/NEW CREW. PUMP WIRELINE/LATCHING DEVICE DOWN, LATCHED UP AT 9127'. CSLLIBRATION READINGS NOT GOOD ON 2 WIRES. ~TCHED{ CIRC TO CLEAR POSSIBLE DEBRIS OFF OF LATCH-UP DEVICE. LATCHED ON AGAIN{ READINGS NO GOOD. POH W/ WIRELINE AT REPORT TIME .... FOUND CABLE IS STRANDED .... 4.00 -- -- 1210 ~ 30 1500 ~ 50 TIME (HRS) CUM. ROT. HRS 250.00 ROTAT I NG MUD MOTOR TRIPPING 12.00 C & C 4.50 REAM I NG SURVEYS JET REPAIRS FISHING NIP UP/DOWN /BOP/WH TESTING BOP /WH RUNNING CASING CEMENTING PICkUP/LAY DOWN DS INSPECT BHA RIG UP/TEAR DOWN WAIT ON WEATHER/MAT EVALUATION 7.00 CORING SWEP""'--~.ASKA DAILY DRILLING REPORT ~- NAME PLATFORM "A" PROG. DEPTH 11943 ) MIDDLE GROUND SHOAL PRESENT DEPTH 11994 LEASE PLATFORM "A" FOOTAGE DRILLED WELL A24-01LE SIZE OF LAST CSG 7.000 WORK ORDER 723530 DEP. OF LAST CSG 10013 SIDE TRACK WATER DEPTH 80 DRILLING FOREMAN: WELLS R V /FREDERICK DA PRESENT ACTIVITY: LOGGING PAGE 1 OF 1 ELEVAT. KB TO MSL l16.& DATE 04/19/95 DIST. KB TO BHF 38.4 DAY 28 NLTA LTH/YTD / EST. DAY 22 LTA LTH/YTD / DAYS +/- DAYS SINCE LAST LTA 744 LAST BOP TEST 04/14/95 LAST CSG TEST 03/26/95 BHA INSPECTION (CUM. ROT HRS) PP1 ~ KILL SPEED 1210 ® 30 PP2 ~ KILL SPEED 1500 ~ 50 SUMMARY OF OPERATIONS (SHOW HOURS FOR'EACH OPERATION) : 5.50 REPAIR STRANDED WIRELINE - RIH TO 8700' - PUMP WIRELINE LATCHING DEVICE DOWN ~ LATCH UP TOOLS ~ 9127' 5.50 RIH (LOGGING) WITH TBG CONVEYED ~ING TOOLS FROM 9475' TO 11993' POOH LOGGING FkOM 11993' TO 11565' - RIH FOR REPEAT SECTION TO 11987' POOH LOGGING - TOOL FAILURE ~ 11868' 1.50 POOH TO SIDE ENTRY SUB FOR REPAIR - LINE SEVERED 6' UP FROM SIDE ENTRY SUB 5.50 POOH WITH WIRELINE - CHANGE OUT WIRELINE SPOOLS - RIG UP NEW WIRELINE MAKE UP SIDE ENTRY SUB 4.50 RIH WITH TBG CONVEYED LOGGING TOOLS - PUMP WIRELINE LATCHING DEVICE DOWN - LATCH UP - RIH TO 11875' - POOH LOGGING TO 11480' - RIH TO 11875' (SLOW) 1.50 POOH LOGGING TIME (HRS) CUM. ROT. HRS 250.00 ROTATING MUD MOTOR TRIPPING C & C REAMING SURVEYS JET REPAIRS FISHING NIP UP/DOWN /BOP/WH TESTING BOP /WH RUNNING CASING CEMENTING PICKUP/LAY DOWN DS INSPECT BHA RIG UP/TEAR DOWN WAIT ON WEATHER/MAT EVALUATION 24.00 CORING OTHERS SWEPI ~KA DAILY DRILLING REPORT PAGE 1 OF 1 RIG NAME PLATFORM "A~ PROG. DEPTH 11943 D MIDDLE GROUND SHOAL PRESENT DEPTH 11994 ~_.~E PLATFORM "A~ FOOTAGE DRILLED WELL A24-01LE SIZE OF LAST CSG 7.000 WORK ORDER 723530 DEP. OF LAST CSG 10013 SIDE TRACK WATER DEPTH 80 ELEVAT. KB TO MSL 116.0 DATE 04/20/95 DIST. KB TO BHF 38.4 DAY 29 NLTA LTH/YTD / EST. DAY 22 LTA LTH/YTD / DAYS +/o DAYS SINCE LAST LTA 745 LAST BOP TEST 04/14/95 LAST CSG TEST 03/26/95 DRILLING FOREMAN: WELLS R V /FREDERICK DA PRESENT ACTIVITY: POOH WITH BIT #15RR SUM]~3%RY OF OPERATIONS (SHOW HOURS FOR EACH OPERATION) : 1.00 FINISH POOH LOGGING - LOG FROM 11875' TO 9292' 2.00 POOH WITH WIRELINE - RIG DOWN SWS .50 CHECK FLOW - PUMP DRY JOB 3.50 POOH WITH TBG CONVEYED ~ING TOOLS 1.00 MAKE UP CLEAN OUT ASSY AND BIT ~15RR 4.50 TIH - FILL PIPE ~ 5000' AND TOW - REAM FROM 11979' TO 11994' 3.00 CIRCULATE AND CONDITION WELL 2.00 SHORT TRIP TO 7" CASING WINDOW - TIH TO 11994' 4.00 CIRCULATE AND CONDITION WELL - WORK PIPE SLOW RUN CENTRIFUGE---REDUCE MUD WGT FROM 12.1 TO 11.8 PPG .50 CHECK FLOW - PUMP DRY JOB 2.00 POOH WITH CLEAN OUT ASSY AND BIT #15RR BHA INSPECTION (CUM. ROT HRS) PP1 ~ KILL SPEED PP2 ~ KILL SPEED 1330 @ 30 1860 @ 50 TIME (HRS) CUM. ROT. HRS 250.00 ROTATING MUD MOTOR TRIPPING 10.00 C & C 7.00 REAMING SURVEYS JET REPAIRS FISHING NIP UP/DOWN /BOP/WH TESTING BOP /WH RUNNING CASING CEMENTING PICKUP/LAY DOWN DS INSPECT BHA RIG UP/TEAR DOWN WAIT ON WEATHER/MAT EVALUATION 7.00 CORING SWEPI Ifa DAILY DRILLING REPORT PAGE 1 OF 1 RI~ NAME PLATFORM "A" PROG. DEPTH 11943 ! MIDDLE GROUND SHOAL PRESENT DEPTH 11994 L~.SE PLATFORM "A' FOOTAGE DRILLED WELL A24-01LE SIZE OF LAST CSG 7.000 WORK ORDER 723530 DEP. OF LAST CSG 10013 SIDE TKACK WATER DEPTH 80 ELEVAT. KB TO MSL 116.0 DATE 04/21/95 DIST. KB TO BHF 38.4 DAY 30 NLTA LTH/YTD / EST. DAY 22 LTA LTH/YTD / DAYS +/- DAYS SINCE LAST LTA 746 LAST BOP TEST 04/14/95 LAST CSG TEST 03/26/95 DRILLING FOREMAN: WELLS R V PRESENT ACTIVITY: CIRCLU. J~TING /FREDERICK DA SUMMARY OF OPERATIONS (SHOW HOURS FOR F~ACH OPERATION) : 1.50 FINISH POOH WITH CLEAN OUT ASSY .50 LAYDOWN BHA 1.50 RIG UP TO RUN 5" LINER - HOLD S/~FETY AND PROCEDURE MEETING 5.50 PICK UP 5" LINE~ o MAKE UP FLOAT SHOE, 1 JT 5" (46.31') DBL VALVE BHA INSPECTION (CUM. ROT HRS) PP1 ~ KILL SPEED PP2 · KILL SPEED FLOAT COLLAR, LARDING COLLAR, 61 JTS 5" (2758.58'), BAKER HYFLO LINER HANGER - FILL LINER EVERY 5 JTS 5.00 RIH WITH 5' LINER ON 3-1/2" DP - FILL DP EVERY 10 STDS TO TOW - RUN IN OPEN HOLE WITHOUT STOPPING TO FILL PIPE 10.00 PICK UP CEMENT HEAD WITH HARD LINES - BREAK CIRCULATION - TAG BOTTOM - CIRCULATE AND CONDITION HOLE FOR CEMENT JOB - WORK PIPE - LOSING APPROX. 6 BPH ~ 55 SPM - SLOW DOWN SPM AND MONITOR - NO FLUID LOSS 30 SPM - CIRCULATE 3 COMPLETE CIRCULATIONS CASING DETAIL: SHOE ~ 11994.00' 1 JT 5" % 11992.52' FC % 11946.21' LC ~ 11944.65' 61 JTS 5" ~ 11943.09' LINER HGR ~ 9183.48' TOL % 9170.38' (TURBECO TYPE "W" CENTRALIZERS INSTALLED EVERY 20') 1330 ~ 30 1860 ~ 50 TIME (HRS) CUM. ROT. HRS 250.00 ROTATING MUD MOTOR TRIPPING 6.50 C & C 10.00 REAMING SURVEYS JET REPAIRS FISHING NIP UP/DOWN /BOP/WH TESTING BOP /WH RU1TNING CASING 5.50 CEMENTING PICIfUP/LAY DOWN DS .50 INSPECT BHA RIG UP/TEAR DOWN WAIT ON WEATHER/MAT EVALUATION CORING OTHERS 1.50 SWEPI ALASKA DAILY DRILLING REPORT PAGE I OF 1 RIG NAME PLATFORM "A" PROG. DEPTH 11943 ) MIDDLE GROUND SHOAL PRESENT DEPTH 11994 Lm.-.SE ~ PLATFORM ~A" FOOTAGE DRILLED WELL A24-01LE SIZE OF LAST CSG 7.000 WORK ORDER 723530 DEP. OF LAST CSG 10013 SIDE TRACK WATER DEPTH 80 ELEVAT. KB TO MSL 116.0 DATE 04/22/95 DIST. KB TO BHF 38.4 DAY 31 NLTA LTH/YTD / EST. DAY 22 LTA LTH/YTD / DAYS +/- DAYS SINCE LAST LTA 747 LAST BOP TEST 04/14/95 LAST CSG TEST 03/26/95 DRILLING FOREMAN: WELLs N V PRESENT ACTIVITY: DRILLING CEMENT /FREDERICK DA SUMMARY OF OPERATIONS (SHOW HOURS FOR EACH OPERATION) : .50 HOLD SAFETY AND PROCEDURE MEETING FOR CEMENT JOB BHA INSPECTION (CUM. ROT HRS) PP1 ~ KILL SPEED PP2 ~ KILL SPEED 1.00 CIRCULATE TO DETERMINE FLUID LOSS ~ 55 SPM - NO FLUID LOSS ~ 40 SPM 2.00 RIG UP HOWCO - PUMP 20 BBLS MIN. OIL PREFLUSH - TEST LINES TO 5000# ~ PUMP 40 BBL 12.0 PPG SPACER - PUMP 448 SXS PREMIUM CEMENT, .2% CFR-3, 1% HR-5~ HAJuAD 344L, LOSURF 300 - DISPLACE WITH 5 BBL SPACER, 5 BBL PREFLUSH, 45 BBLS 11.9 PPG MUD, 23 BBLS 16 PPG MUD, 45 BBLS 11.9 PPG M-t/D (4 BBLS OVER) - BUMPED PLUG ~ 3500~ BLEED OFF PRESSURE - ROTATE OFF HANGER - RIG DOWN CEMENT HEAD (RECIPROCATE PIPE UNTIL 65 BBLS CEMENT WAS PAST THE SHOE - SET PIPE IN TENSION - FINISHED PUMPING CEMENT) 1.00 POOH 30 STDS (SLOW) - MAKE UP TOP DRIVE 1.50 CIRCI]T0~TE TO CLEAR PIPE - CHECK FLOW - PUMP DRY JOB 2.00 POOH WITH LINER SETTING TOOL - LAY DOWN LAST 9 JTS DP .50 MAICE UP CLEAN OUT ASSY WITH BIT #4RR 2.50 RIH - TAG CEME1TT ~ 7315' 13.00 BREAK CIRCULATION - DRILL CEMENT FROM 7315' TO 8760' 1530 ~ 30 2130 ~ 50 TIME (HRS) CUM. ROT. HRS 263.00 ROTATING 13 . 00 MUD MOTOR TRIPPING 6.00 C & C 2.50 REAMING SURVEYS JET RE PA I RS FISHING NIP UP/DOWN /BOP/WH TESTING BOP /WH RUNNING CASING CEMENTING 2.00 PICKUP/LAY DOWN DS INSPECT BHA RIG UP/TEAR DOWN WAIT ON WEATHER/MAT EVALUAT I ON COR I NG SWEPI KA DAILY DRILLING REPORT PAGE 1 OF 1 ~'- NAME PLATFORM "A" PROG. DEPTH 11943 ) MIDDLE GROUND SHOAL PRESENT DEPTH 11994 LEASE PLATFORM WA' FOOTAGE DRILLED WELL A24-01LE SIZE OF LAST CSG 7.000 WORK ORDER 723530 DEP. OF LAST CSG 10013 SIDE TRACK WATER DEPTH 80 ELEVAT. KB TO MSL 116.0 DATE DIST. KB TO BHF 38.4 DAY NLTA LTH/YTD / EST. DAY LTA LTH/YTD / DAYS +/- DAYS SINCE LAST LTA 748 o4/23/95 32 22 L~T BOP TEST 04/14/95 LAST CSG TEST 03/26/95 DRILLING FORF34AN: WELLS R V PRESENT ACTIVITY: PUMPING DRY JOB /FREDERICK DA - . SUMMARY OF OPERATIONS (SH6W HOURS FOR EAC~ OPERATION) : 4.50 DRILL CEMENT FROM 8760' 'TO 9168' (TOL) BHA INSPECTION (CUM. ROT HRS) PP1 · KILL SPEED PP2 % KILL SPEED 1.50 CIRCULATE BOTTOMS UP ~ 9168' - PRESSURE TEST LINER TOP ~ 7" CASING TO 1500# FOR 10 MIN. ~ HELD OK 2.50 POOH WITH CLEAN OUT ASSY AND BIT #4RR 1.50 LAY DOWN BHA RIG UP 2-7/8w EQUIPMENT - MAKE UP 4-1/8" MILL AND 3-1/8" DC'S 4.50 RIH WITH 2-7/8" AND 3-1/2w DP TO TOL 1.00 BREAK CIRCULATION - DRILL CEMENT FROM 9168' TO 9175' 3.50 RIH - CLEAN OUT CEMENT STRINGERS - TAG CEMENT ~ 11752' - DRILL TO 11941' (TOP OF LANDING COLLAR) 2.50 CIRCULATE BOTTOMS UP ~ 11941' .50 PRESSURE TEST 5" LINER TO 1500# FOR 10 MIN. - HELD OK 2.00 CIRCULATE AND CONDITION 'MUD - PUMP DRY JOB 2850 ~ 30 ~ 50 TIME (HRS) CUM. ROT. HRS 270.50 ROTATING 7.50 MUD MOTOR TRIPPING 8.50 C & C 5.50 REAMING SURVEYS JET REPAIRS FISHING NIP UP/DOWN /BOP/WH TESTING BOP /WH RUNNING CASING CEMENTING PICKUP/LAY DOWN DS .50 INSPECT BHA RIG UP/TEAR DOWN WAIT ON WEATHER/MAT EVALUATION CORING OTHERS 2.00 SWEPI ALASKA DAILY DRILLIN~ REPORT PAGE 1 OF 1 ~Tc NAME PLATFORM "A" PROG. DEPTH 11943 D MIDDLE GRO[/ND SHOAL PRESENT DEPTH 11994 LEASE PLATFORM WAW FOOTAGE DRILLED WELL A24-01LE SIZE OF LAST CSG 5.000 WORK ORDER 723530 DEP. OF LAST CSG 11994 SIDE TRACK WATER DEPTH 80 ELEVAT. KB TO MSL 116.0 DATE 04/24/95 DIST. KB TO BHF 38.4 DAY 33 NLTA LTH/YTD / EST. DAY 22 LTA LTH/YTD / DAYS DAYS SINCE LkST LTA 749 LAST BOP TEST 04/14/95 LAST CSG TEST 03/26/95 DRILLING FOREMAN: WELLS R V PRESENT ACTIVITY: TEST CASING /FREDERICK DA SUMMARY OF OPER~TIONS (SHOW HOURS FOR EACH OPERATION) : 2.00 POOH WITH CLEAN OUT ASSY SLOW (WET) 1.00 MIX AND PUMP DRY JOB 4.00 POOH (WET) - LAY DOWN 4-1/8" MILL 1.50 MAXE UP 5w SCRAPER - RIH WITH 2-7/8" DP 3.50 MAJ{E UP 7w SCRAPER - RIH WITH 3-1/2~ DP (TANDEM ASSY) 6.00 TAG LANDING COLLAR ~ 11941' - CIRCULATE A/rD CONDITION MUD - RUN CENTRIFUGE - WORK A_ND ROTATE PIPE 5.50 REVERSE CIRCULATE OBM OUT OF WELLBORE - DISPLACE WITH FIW - PUMP 20 BBL XA_NVIS SWEEP FOLLOWED WITH FIW - TRANSFER 525 BBLS 11.8 PPG OBM RETURNS TO STORAGE TANK - FLUSH FLOWLINE AND CHOKE MANIFOLD .50 POOH 10 STD DP - RIG UP TO TEST CASING BHA INSPECTION (CUM. ROT HRS) PPI ~ KILL SPEED PP2 ~ KILL SPEED 2850 ~ 30 ~ 50 TIME (HRS) CUM. ROT. HRS 270.50 ROTATING MTJD MOTOR TRIPPING 11.00 C & C 12.50 REAMING SURVEYS JET REPAIRS FISHING NIP UP/DOWN /BOP/WH TESTING BOP /WH RUNNING CASING .. CEMENTING PICKUP/LAY DOWN DS .50 INSPECT BHA RIG UP/TEAR DOWN WAIT ON WEATHER/MAT EVALUATION CORING S~rEP ASKA DAILY DRILLING REPORT ~-, PAGE 1 OF 1 ~ 2AME PLATFORM "A" PROG. DEPTH 11943 FIELD MIDDLE GROUND SHOAL PRESENT DEPTH 11994 LEASE PLATFORM "A" FOOTAGE DRILLED WELL A24-01LE SIZE OF LAST CSG 5.000 WORK ORDER 723530 DEP. OF LAST CSG 11994 SIDE TRACK WATER DEPTH 80 ELEVAT. KB TO MSL 116.0 DATE 04/25/95 DIST. KB TO BHF 38.4 DAY 34 NLTA LTH/YTD / EST. DAY 22 LTA LTH/YTD / DAYS +/- DAYS SINCE LAST LTA 750 LAST BOP TEST 04/14/95 LAST CSG TEST 04/24/95 DRILLING FOREMAN: WELLS R V PRESENT ACTIVITY: POOH /FREDERICK DA SUMMARY OF OPERATIONS (SHOW HOURS FOR -EACH OPERATION) : 1.00 PRESSURE TEST 7" AND 5" CASING TO 2500# FOR 30 MIN - HELD OK 3.00 POOH TO 7" SCRAPER .50 CIRCUI. J{TE BOTTOMS UP-WITH FIW BHA INSPECTION (CUM. ROT HRS) PP1 ~ KILL SPEED ~ 30 PP2 % KILL SPEED ~ 50 5.00 RIH WITH TANDEM SCRAPER ASSY TO 11941' - LAY DOWN 29 JTS HWDP, JARSf AND 6 DC'S 10.50 CLOSE HYDRIL - REVERSE CIRCULATE 25 BBL HIGH VIS SWEEP - CIRCULATE CONVENTIONAL 10 BBL HIGH VIS SWEEP, 10 BBL FIW, 10 BBL HIGH VIS SWEEP, CHASE WITH FIW - WORK AND ROTATE PIPE - CIRCULATED ANOTHER SERIES OF 10 BBL SWEEPS - WORK AND ROTATE PIPE - REVERSE CIRCUI. J%TE 36 BBL HIGH VIS SWEEP - CHASE WIT}{ FIW - NTU ~ 58 4.00 POOH WITH TANDEM SCRAPER ASSY - CHECK TOOL JTS FOR WEAR TIME (HRS) CUM. ROT. HRS ROTATING MUD MOTOR TRIPPING C & C REAMING SURVEYS JET REPAIRS FISHING NIP UP/DOWN /BOP/WH TESTING BOP /WH RUNNING CASING CEMENTING PICKUP/LAY DOWN DS INSPECT BHA RIG UP/TEAR DOWN WAIT ON WEATHER/MAT EVALUATION CORING 270.50 12.00 11.00 SWEPI ALASKA DAILY DRILLING REPORT PAGE 1 OF 1 RIG NAME PLATFORM "A" PROG. DEPTH 11943 ? ~ MIDDLE GROUND SHOAL PRESENT DEPTH 11994 L ~ PLATFORM "A~ FOOTAGE DRILLED WELL A24-01LE SIZE OF LAST CSG 5.000 WORK ORDER 723530 DEP. OF LAST CSG 11994 3IDE TRACK __ WATER DEPTH 80 ELEVAT. KB TO MSL 116.0 DATE 04/26/95 DIST. KB TO BHF 38.4 DAY 35 NLTA LTH/YTD __/__ EST. DAY 22 LTA LTH/YTD / DAYS +/- DAYS SINCE LAST LTA 751 LAST BOP TEST 04/25/95 LAST CSG TEST 04/24/95 DRILLING FOREMAN: SELTZ RH . PRESENT ACTIVITY: PREPARING TO PERFORATE /FREDERICK DA 3UMFJuRY OF OPERATIONS (SHOW HOURS FOR EACH OPERATION) : 4.00 FINISH POOH WITH TANDEM SCRAPER ASSY 5.00 TEST BOP'S 1.00 HOLD SAFETY AND PROCEDURE MEETING FOR PERFORATING WITH ALL PLATFORM PERSONNEL - (PRODUCTION, CONSTRUCTION AND DRILLING) BHA INSPECTION (CUM. ROT HRS) PP1 % KILL SPEED @ 30 PP2 ~ KILL SPEED ~ 50 il.50 PICK UP PERFORATING GUNS AND PACKER ASSY - RIH - FILL PIPE WITH FIW TO 4300' - CHECK FOR LEAKS ON TRIP IN HOLE 2.50 RIG UP SWS WIRELINE - RIH WITH GR LOG TO CORRELATE - POOH WITH WIRELINE NOTE: PAT THOMPSON (IDA DERRICKMAN) NOTICED A SHEEN FLOWING IN THE INLET % APPROX. 9:00 AM - IT WAS DISCOVERED THAT A UNION ON THE DRAIN PAN LINE UNDER THE CRANE WAS LOOSE - IT WAS ESTIMATED AND REPORTED THAT LESS THAN A QUART OF DIESEL/WATER MIXTURE WAS RET,RASED INTO THE INLET TIME (HRS) CUM. ROT. HRS 270.50 ROTATING MUD MOTOR TRIPPING 15.00 C & C REAMING SURVEYS JET REPAIRS FISHING NIP UP/DOWN /BOP/WH TESTING BOP /WH 5.00 RUNNING CASING CEMENTING PICKUP/LAY DOWN DS .50 INSPECT BHA RIG UP/TEAR DOWN WAIT ON WEATHER/MAT EVALUATION CORING OTHERS 3.50 SWEP] ~KA DAILY DRILLING REPORT ! lAME PLATFORM "A' PR(X]. DEPTH 11943 F,_~D MIDDLE GROUND SHOAL PRESENT DEPTH 11994 LEASE PLATFORM 'A" FOOTAGE DRILLED WELL A24-01LE SIZE OF LAST CSG 5,000 WORK ORDER 723530 DEP. OF LAST CSG 11994 SIDE TRACK WATER DEPTH 80 DRILLING FOREMAN: SELTZ RH /FREDERICK DA PRESENT ACTIVITY: RIH WITH PRODUCTION TUBING PAGE 1 OF 1 ELEVAT. KB TO MSL 116,0 DATE 04/27/95 DIST. KB TO BHF 38,4 DAY 36 NLTA LTH/YTD / EST. DAY 22 LTA LTH/YTD __/~ DAYS +/- DAYS SINCE LAST LTA 752 LAST BOP TEST 04/25/95 LAST CSG TEST 04/24/95 BHA INSPECTION (CUM. ROT HRS) PP1 ~ KILL SPEED @ 30 PP2 % KILL SPEED ® 50 .. SUMMARY OF OPERATIONS (SHOW HOURS FOR EACH OPERATION) : 7,50 RIG UP SWS TREE ASSY ON TOP OF TIW VALVE - PICK UP DP 7' TO 11778' - SET PACKER ~'11660' - RIG UP CHOKE AND FLOW LINES - TEST LINES TO 2500~ - CLOSE PIPE R3~4S - PRESSURE UP ON ANNI3LUS TO 1250# - GUNS FIRED AND PACKER RELEASED - PRESSURE BLED OFF - MONITOR ANNULUS AND DP PRESSURE o SHOOT FLUID LEVELS @ 10 MIN INTERVALS - FLUID % 5700' AND HOLDING - GUNS WERE FIRED @ 10:28AM 3.00 RELEASE PACKER - CLOSE PIPE RAMS - REVERSE CIRCULATE @ 2 BPM - RETURNS TO PITS - PULL SAMPLES OF RETURNS EVERY 5 MIN - (PUMPED 5 BBL TO GET RETURNS - PUMPED 100 BBL TOTAL) - CHECK FLOW - CIRCULATE CONVENTIONAL ONE COMPLETE CIRCULATION 1.00 CHECK FLOW - PUMP DRY JOB - LAY DOWN SWS TREE ~Z~ND MANIFOLD 5.50 POOH TO PERFORATING ASSY 1.00 HOLD SAFETY MEETING PRIOR TO PULLING AND LAYING DOWN PERF EQUIPMENT 4.00 INSTALL 2-7/8 PIPE RAMS ~ TEST PIPE R3%MS AND HYDRIL - PULL WEAR RING 1.00 RIG UP TO RUN PRODUCTION TUBING - HOLD SAFETY ~ PROCEDURE MEETING 1.00 RIH WITH PRODUCTION TUBING NOTE: PRODUCTION SERVICES FLUID LEVEL EQUIPMENT FAILED - USED SWS ECHOMETER - FLUID LEVEL DATA WAS QUESTIONABLE TIME (HRS) CUM. ROT. HRS ROTATING MUD MOTOR TRIPPING C&C REAM I NG SURVEYS JET RE PA I RS FISHING NIP UP/DOWN /BOP/WH TESTING BOP /WH RUNNING CASING CEMENT I NG PICKUP/LAY DOWN DS INSPECT BRA RIG UP/TEAR DOWN WAIT ON WEATHER/MAT EVALUAT I ON C 0 R I NG OTHERS 270.50 6.50 3.00 4.00 10.50 SWEPI A3_J~SKA DAILY DRILLING REPORT PAGE 1 OF 1 RIG NAME PLATFORM "A" PROG. DEPTH 11943 ELEVAT. KB TO MSL D MIDDLE GROUND SHOAL PRESENT DEPTH 11994 DIST. KB TO BHF 116.0 DATE 38.4 DAY L~,,SE PLATFORM "A" FOOTAGE DRILLED NLTA LTH/YTD / WELL A24-01LE SIZE OF LAST CSG 5.000 LTA LTH/YTD / WORK ORDER 723530 DEP. OF LAST CSG 11994 DAYS SINCE LAST LTA SIDE TRACK DRILLING FOREMAN: SELTZ RH PRESENT ACTIVITY: RIH WITH SLU WATER DEPTH 80 /FREDERICK DA S~Y OF OPERATIONS (SHOW HOURS FOR EACH OPERATION) : 10.50 PICK UP AND RIH WITH PRODUCTION TUBING 2.00 MAKE UP SSSV AND CONTROL LINE - TEST TO 5000# 04/28/95 37 753 EST. DAY 22 DAYS +/- LAST BOP TEST 04/25/95 LAST CSG TEST 04/24/95 BHA INSPECTION (CUM. ROT HRS) PP1 @ KILL SPEED @ 30 PP2 @ KILL SPEED @ 50 3.00 PICK UP TBG HANGER - THREADS ON TOP OF HANGER WERE GAULED BY TBG PUP USED TO PICK UP - TAKE HANGER TO MACHINE SHOP TO DRESS THREADS - CIRCULATE 2-1/2 TBG VOLUMES TO CLEAN TBG WHILE GETTING HANGER DRESSED .50 MAKE UP HANGER AND CONTROL LINE - LAND TBG HANGER IN SPOOL 8.00 RIG UP SLU - TEST LUBRICATOR TO 3500# - RIH WITH "N" TOOL - SET IN "XN" NIPPLE ~ 9868' - PUMP DOWN TBG WITH TEST PUMP - MONITOR ANNULUS - ATTEMPT TO PRESSURE UP ON TUBING (NO GOOD) - "N" TOOL WILL NOT SEAT IN "XN" NIPPLE - POOH WITH "N" TOOL - RIH WITH PRONG AND PLUG ASSY - ATTEMPT TO SET IN "XN" NIPPLE (NO GOOD) - POOH - MAKE UP ADDITIONAL WGT BARS AND "N" TEST TOOL - INSTALL PUMP-IN SUB TO LUBRICATOR - RIH WITH "N" TEST TOOL ON SLU -. TIME (HRS) CUM. ROT. HRS ROTATING MUD MOTOR TRIPPING C & C REAMING SURVEYS JET REPAIRS FISHING NIP UP/DOWN /BOp/wH TESTING BOP /WH RUNNING CASING CEMENTING PICKUP/LAY DOWN DS INSPECT BRA RIG UP/TEAR DOWN WAIT ON WEATHER/MAT EVALUATION CORING 270.50 10.50 3.00 RIG NAME PLATFORM "A" FIELD MIDDLE GROUND SHOAL LF PLATFORM "A" gE. A24-O1LE UORK ORDER 723530 sh~eI ALASKA DAILY DRILLING REPORT PROG. DE~TH 11943 ELEVAT. KB TO MSL 116.0 PRESENT DEPTH 11994 DIST. KB TO BHF 38.4 FOOTAGE DRILLED NLTA LTH/YTD / SIZE OF LAST CSG 5.000 LTA LTH/YTD / DEP. OF LAST CSG 11994 DAYS SINCE LAST LTA 754 PAGE 1 OF 1 DATE ~4/2~/95 DAY 3~ EST. DAY 22 DAYS +/- SIDE TRACK DRILLING FOREMAN: SELTZ RH PRESENT ACTIVITY: RIG RELEASED WATER DEPTH 80 /FREDERICK DA SUMMARY OF OPERATIONS (SHOW HOURS FOR 'EACH OPERATION) : 3.00 NIH WITH "N." TEST PLUG - ATTEMPT TO SET PACKER WITH RIG PUMP TO 2500# LAST BOP TEST ~4_~/9~ LAST CSG TEST ~4/24__4~ BHA INSPECTION (CUM. ROT HRS) PP1 @ KILL SPEED @ 30 PP2 @ KILL SPEED @ 50 WOULD NOT HOLD PRESSURE - POOH - LEFT PLUG IN HOLE -RIH - RETREIVE PLUG - POOH 4:50 RIH WITH GLM POCKET IMPRESSION BLOCK - POOH - #10 GLM VALVE POCKET IS EMPTY - MAKE UP VALVE ON KICK OVER TOOL - RIH - INSTALL VALVE IN #10 GLM - POOH 3.00 NIH WITH "N" TEST TOOL - PRESSURE UP WITH RIG PUMP TO 1000# - SET PACKER @ 9823~ - PRESSURE TBG TO 2500# - MONITOR ANNULUS - PRESSURE ANNULUS TO 1500# - BLEED C;-F PRESSURE - POOH - CLOSE SSSV - RD SLU 7.50 SET BPV - NIPPLE DOWN BOPfS - HOLD SAFETY AND PROCEDURE MEETING - LAY DOWN RISER - INSTALL AND NIPPLE UP TREE' ASSY - TEST TREE TO 5000# - INSTALL FLOWLINES - TEST TREE TO 5000# . . NOTE: RIG RELEASED 04[~8_~9._5 @ 12:00 AM TIME (ERS1 I CUM. ROT. HRS I ROTATING MUD MOTOR TRIPPING Ic&c REAMING SURVEYS JET REPAIRS FISHING NIP UP/DOWN /BOP/WH TESTING BOP RUNNING CASING CEMENTING PiCKUP/LAY DOWN DS INSPECT RiG UP/TEAR DOgR ~A[T OR ~EATHER/MAT EVALUATION CORIRG OT~ERS SWEP~ ALASKA DAILY DRILLING REPORT 270.50 18". 50 PAGE I OF 1 RIG "AME PLATFORM "A" FI MIDDLE GROUND SHOAL LEA~m PLATFORM "A" UELL A24-O1LE UORK ORDER 723530 SIDE TRACK DRILLING FOREMAN: SELTZ RH PROG. DEPTH 1~943 PRESENT DEPTH FOOTAGE DRILLED SIZE OF LAST CSG 5.000 DEP. OF LAST CSG 11994 WATER DEPTH 80 /GALLOWAY DR PRESENT ACTIVITY: UNSEATING PROD PACKER SUMMARY OF OPERATIONS (SHOU HOURS FOR~EACH OPERATION) : 3.50 SKID RIG OVER A24-OILE AND COMPLETE RIG UP. ELEVAT. KB TO MSL 116.0 DATE DIST. KB TO BHF 38.4 DAY 39 NLTA LTH/YTD / EST. DAY 22 LTA LTH/YTD ___/___ ~ DAYS +/- DAYS SINCE LAST LTA 755 LAST BOP TEST 05_~/9~ LAST CSG TEST ~4/24/95 BHA INSPECTION (CUM. ROT HRS) PP1 @ KILL SPEED @ 30 , ., PP2 @ KILL SPEED @ 50 8.50 HELD PRE-JOB SAFETY MEETING. SET BPV AND REMOVED WELLHEAD TREE. INSTALLED RISER AND BOP STACK. COMPETED R/U OF BOP AND ASSOCIATED EQUIPMENT.'- 4.00 PERFORM SUCCESSFUL TEST OF BOP~S AND ALARMS. 2.00 REMOVE BPV AND INSTALL LANDING JT. BACK oUT LOCKING PINS AND PREP TO UNSEAT PACKER. NOTE: RIG ACCEPTED ON A24-OILE AT 12:00 t TIME ~RS1 CUM. ROT. HRS 270.50 ROTATING MUD MOTOR TRIPPING C&C REAMING SURVEYS JET REPAIRS FISHING NIP UP/DOWN /BOP/UH 8.50 TESTING BOP /WH 4.00 RUNNING CASING CEMENTING PICKUP/LAY DOWN DS INSPECT BHA RIG UP/TEAR DOUN 5.50 WAIT ON WEATHER/MAT EVALUATION CORING OTHERS SUEPI ALASKA DAILY DRILLING REPORT PAGE 1 OF 1 PROG. DEPTH 11943 PRESENT DEPTH FOOTAGE DRILLED SIZE OF LAST CSG 5.000 DEP. OF LAST CSG 11994 WATER DEPTH 80 RIG NAME PLATFORM "A" FIELD MIDDLE GROUND 3HOAL LE' - PLATFORM "A" UE A24-OILE WORK ORDER 723530 SIDE TRACK DRILLING FOREMAN: SELTZ RH PRESENT ACTIVITY: ~/U PERFORATION /GALLOgAY D~ ASSEMBLY SUMMARY OF .OPERATIONS (SHOW HOURS FOR EACH OPERATION) : .50 UNSEAT PRODUCTION PACKER. 2.50 CIRCULATE HOLE WITH CLEAN FIU. 1.00 CHECK FLOg AND REMOVE LANDING JT. ELEVAT. KB TO MSL 116.0 DATE DIST. KB TO BHF 38.4 DAY 40 NLTA LTH/YTD / EST. DAY 22 LTA LTH/YTD / DAYS +/- DAYS SINCE LAST LTA' 756 LAST BOP TEST ~5/~/9~ LAST CSG TEST BHA INSPECTION (CUM. ROT HRS) PP1 @ KILL SPEED @ 30 PP2 @ KILL SPEED @ 50 4.00 INSTALL MOUSE HOLE AND LAY DOWN 2 Z/8 PH6 TBG AND REARRANGE DRILLPIPE IN DERRICK DUE TO SIZING LIMITATIONS. 2.00 ~/U LANDING JT AND CIRCULATE BOTTOMS UP AND CHECK FOR FLOW. 6.50 POH WITH PRODUCYION EQUIPMENT. 3.50 CHANGE OUT BOP PIPE RAMS AND SUCCESSFULLY TEST RAMS. 4.00 HELD PRE-JOB SAFETY MEETING. RU SWS AND_~EGI~ l'~ ~[U_2___ZZ8 TBG CONVEYED PERF GUNS. TIME CUM. ROT. HRS ROTATING MUD MOTOR TRIPPING C&C R.EAMING SURVEYS JET REPAIRS FISHING .NIP UP/DOWN /BOP/UN TESTING BOP /UN RUNNING CASING CEMENTING PICKUP/LAY DOWN DS INSPECT BHA RIG UP/TEAR DOWN WAIT ON WEATHER/MAT EVALUATION CORING OTHERS 270.50 7.00 4.50 2.00 4.00 6.50 SWEPI ALASKA DAILY DRILLING REPORT PAGE 1 OF 1 RIG NAME PLATFORM "A" PROG. DEPTH 11943 ' ) MIDDLE GROUND SHOAL PRESENT DEPTH L~,.~E PLATFORM "A" FOOTAGE DRILLED WELL A24-01LE SIZE OF LAST CSG 5.000 WORK ORDER 723530 DEP. OF LAST CSG 11994 SIDE TRACK__ WATER DEPTH 80 ELEVAT. KB TO MSL 116.0 DATE 05/05/95 DIST. KB TO BHF 38.4 DAY 41 NLTA LTH/YTD / EST. DaY 22 LTA LTH/YTD / DAYS +/- DAYS SINCE LAST LTA 757 LAST BOP TEST 05/03/95 LAST CSG TEST 04/24/95 DRILLING FOREMAN: SELTZ RH PRESENT ACTIVITY: POH WITH PERF ASSEMBLY /GALLOWAY DR BHA INSPECTION (CUM. ROT HRS) PP1 ~ KILL SPEED ~ 30 PP2 ~ KILL SPEED ~ 50 SUMMARY OF OPERATIONS (SHOW HOURS FOR EACH OPERATION) : 14.50 CONT. TO P/U SWS PERF ASSEMBLY AND RIH WITH THE SAME ON 2 7/8 PH6 TBG AND 3.5 DRILLPIPE. FILLED PIPE AT 3400'. CONT TO RIH WITHOUT FILLING DP AGAIN. PACKER BEGAN TO TAKE WT AT PACKER DEPTH OF 9856'. ATTEMPTED TO WORK PAST 9856' WITHOUT SUCCESS. POH WITH PACKER TO ABOVE LINER HANGER IN ATTEMPT TO WASH OFF POSSIBLE TRASH. RIH WITH ASSEMBLY. DID NOT HANG UP AT 9856'. RIH TO 10200' WITH TOP SHOT, BOTTOM SHOT AT 11,786', RA COLLAR AT 9978'. 2.50 RUWL (SWS). RIH WITH GR AND CORRELATED DP MEASUREMENT TO WIRELINE MEJ%SUREMENT. RU STEEL HOSE TO TEST SEPER. ATOR. POH WITH GR TOOL. RDWL. REPOSITION DP TO HAVE BOTTOM OF GUNS AT 11,783' BY DRILL PIPE MEASUREMENT. 2.00 ATTEMPTED TO SET SWS PACKER MULTIPLE TIMES WITHOUT SUCCESS. 5.00 CHECK FLOW AND BEGAN TO POH WITH SWS PERF ASSEMBLY. NOTE: WELL FLOWING AT 1.5 BPH. TIME (HRS) CUM. ROT. }{RS ROTAT I NG MUD MOTOR TRIPPING C &C REAMING SURVEYS JET REPAI RS FISHING NIP UP/DOWN /BOP/wH TESTING BOP /W-H RUNNING CASING CEMENT I NG PICKUP/LAY DOWN DS INSPECT BHA RIG UP/TEAR DOWN WAIT ON WEATHER/MAT EVALUAT I ON 270.50 19.50 2.50 SWEPI A~.~KA DAILY DRILLING REPORT PAGE 1 OF 1 RT~ NAME PLATFORM "A" PROG. DEPTH 11943 ) MIDDLE GROUND SHOAL PRESENT DEPTH LEASE PLATFORM "A' FOOTAGE DRILLED WELL A24-01LE SIZE OF LAST CSG 5.000 .. WORK ORDER 723530 DEP. OF LAST CSG 11994 SIDE TRACK WATER DEPTH 80 ELEVAT. KB TO MSL 116.0 DATE 05/06/95 DIST. KB TO BHF 38.4 DAY 42 .. NLTA LTH/YTD / EST. DAY 2--2 LTA LTH/YTD / DAYS +/- DAYS SINCE LAST LTA 758 LAST BOP TEST 05/03/95 LAST CSG TEST 04/24/95 DRILLING FOREMAN: SELTZ R/~ /GALLOWAY DR PRESENT ACTIVITY: PREP TO RIH WITH SCRAPPERS BHA INSPECTION (CUM. ROT HRS) PP1 ~ KILL SPEED ~ 30 PP2 ~ KILL SPEED ~ 50 SUMMARY OF OPERATIONS (SHOW HOURS FOR EACH OPERATION) : 4.50 CONT. TO LAY DOWN PERF GUNS. LAID DOWN PACKER. SEVERE DAMAGE TO PKR. MISSING RUBBERS AND BOTTOM SLIP ELEMENTS. 5.50 RUWL (SWS) RIH WITH 5.97' GAUGE RING/JUNK BASKET, TAGGED UP AT 3040'' COULD NOT WORK DEEPER. POH WITH BASKET. RECOVERED JUNK RUBBER. RIH WITH BASKET AS BEFORE. TAGGED UP AT 7000' - UNABLE TO WORK DEEPER. POH. DID NOT RECOVER ANY JUNK. RDWL. 1.00 M/U 6" BIT AND 7" CASING SCRAPPER ON 1 STD DC'S. 5.00 RIH SLOWLY WITH SCRAPPER AND TAGGED TOP OF LINER AT 9168'. 2.50 BREAK CIRCUIJ~TION. HIGH GAS LEL AT 70%. CLOSE PIPE RAMS AND CIRCLATED WITH CLEAN FIW WITH RETURNS VIA GAS BUSTER. WORKED AND CIRC AT TOL AND ATTEMPT TO FLUSH POSSIBLE JUNK FROM LINER TOP. .50 CHECK FLOW AND PREP TO-~OH. 3.50 POH WITH CASING SCRAPPER ASSEMBLY. 1.50 RUWL (SWS) RIH WITH GR/CERT 5.5 MAGNET ON WIRELINE. TAGGED TOL AND ENGAGED MAG. POH. RECOVERED FINE METAL CUTTINGS. RDWL PREPARING TO RIH WITH TANDEM SCP,~PPER ASSEMBLY AT REPORT-TIME. TIME (HRS) CUM. ROT. HRS 270.50 ROTATING MUD MOTOR TRIPPING 7.50 C & C 2.50 REAMING SURVEYS JET REPAIRS FISHING NIP UP/DOWN /BOP/WH TESTING BOP /WH RUNNING C3tSING CEMENTING PICKUP/LAY DOWN DS 4.50 INSPECT BHA 1.00 RIG UP/TEAR DOWN WAIT ON WEATHER/MAT EVALUATION CORING OTHERS 8.5O SWEPI ALASKA DAILY DRILLING REPORT PAGE 1 OF 1 Rv- NAME PLATFORM. "A' PROG. DEPTH 11943 } , MIDDLE GROUND SHOAL PRESENT DEPTH LEASE PLATFORM 'A" FOOTAGE DRILLED WELL A24-01LE SIZE OF LAST CSG 5.000 WORK ORDER 723530 DEP. OF LAST CSG 11994 SIDE TRACK WATER DEPTH 80 ELEVAT. KB TO MSL 116.0 DATE 05/07/95 DIST. KB T0 BHF 38.4 DAY 43 NLTA LTH/YTD / EST. DAY 22 LTA LTH/YTD . /__ DAYS +/- DAYS SINCE LAST LTA 759 LAST BOP TEST 05/03/95 LAST CSG TEST 04/24/95 DRILLING FOREMAN: SELTZ PRESENT ACTIVITY: RIH WITH WL FOR TIE-IN /GALLOWAY DR BHA INSPECTION (CUM. ROT HRS) PP1 ~ KILL SPEED ~ 30 PP2 ~ KILL SPEED ~ 50 3UMMARY OF OPERATIONS (SHOW HOURS FOR EACH OPERATION) : 5.00 M/U AND RIH WITH TANDOM SCRAPPER ASSEMBLY FOR 5" AND 7" CASING. RIH WITH SCRAPPERS TO ]0207'. 2.00 CLOSE PIPE RAMS AND CIRCULATE AND CONDITION HOLE VIA GAS BUSTER. 3.50 CHECK FLOW AND POH WITH SCRAPPER ASSEMBLY. .50 L/D SCRAPPERS AND ASSOCIATED EQUIPMENT. 4.00 HELD PRE-JOB SAFETY MEETING. P/U TBG CONVEYED PERF GUNS WITH HOWCO PACKER AND RA LOCATOR. 8.00 RIH VERY SLOWLY DUE TO TBG CONVEYED PERF GUNS. FILLED PIPE AT 3400' ONLY. 1.00 RUWL (SWS) RIH WITH GR TO TIE-IN TO RA MARKER. TIEING IN AT REPORT TIME. TIME (HRS) CUM. ~OT. HRS 270.50 ROTAT I NG MUD MOTOR TRIPPING 16 . 50 C & C 2.00 REAMING SURVEYS JET REPAIRS FISHING NIP UP/DOWN /BOP/W}{ TESTING BOP /WH RUNNING CASING CEMENTING PICKUP/LAY DOWN DS .50 INSPECT BHA RIG UP/TEAR DOWN WAIT ON WEATHER/MAT EVALUAT I ON SWEPI ~LASKA DAILY DRILLING REPORT PAGE 1 OF 1 RT' NAME PLATFORM "A" PROG. DEPTH 11943 ) MIDDLE GROUND SHOAL PRESENT DEPTH LEASE PLATFORM "A= FOOTAGE DRILLED WELL A24-01LE SIZE OF LAST CSG 5.000 WORK ORDER 723530 DEP. OF I2kST CSG 11994 SIDE TRACK WATER DEPTH 80 ELEVAT. KB TO MSL 116.0 DATE 05/08/95 DIST. KB TO BHF 38.4 DAY 44 NLTA LTH/YTD / EST. DAY 22 LTA LTH/YTD / DAYS +/- DAYS SINCE LAST LTA 760 LAST BOP TEST 05/03/95 LAST CSG TEST 04/24/95 DRILLING FOREMAN: SELTZ RH /GALLOWAY DR PRESENT ACTIVITY: POH WITH PERF ASSEMBLY SUMMARY OF OPERATIONS (SHOW HOURS FOR EACH OPERATION) : 1.00 2.00 1.00 2.00 3.50 2.50 1.5O 4.50 2.00 .50 3.50 -- CONT. TO TIEkIN WITH SWS GR TOOL. BHA INSPECTION (CUM. ROT HRS) PPi ~ KILL SPEED PP2 ~ KILL SPEED 270 ~ 30 760 ~ 50 P/U STRING 4' 5O PUT-ON CORRECT DEPTH. RDWL AND SET HOWCO PACKER. M/U TEST TREE AND TEST TO 3000~. SHOT BEGINNING FLUID LEVEL AND FOUND FLUID 6417' FROM SURFACE. WILL SHOOT PERIODIC FLUID LEVELS DURING TEST PRESSURED ANNULUS UP TO 1100# WHEN GUNS SHOT AT 8:54 A.M. CONTINUED TO PRESSURE UP TO 2000# AND HELD PSI SEVEP, A,L MINUTES BEFORE RELEASING. PERFORATED FORMATION WITH 4 JSPF FROM A TOP SHOT OF 10r200' TO A BOTTOM SHOT OF 11r786'. ALLOWED WELL TO FLOW FOR TWO HOURS TO TEST AND CLEANUP FORMATION. OPENED BYPASS OF PACKER AND REVERSE CIRCULATED DRILLPIPE CLEAN. CONVENTIONAL CIRCULATED BOTTOMS UP ON CASING ANNULUS. ATTEMPTED TO RELEASE'~OWCO PACEER W/OUT SUCCESS. DISPLACE DRILLPIPE WITH 80 BBLS FIW AND SD TO RECORD BUILD UP PSI. MONITOR WELL AND WEIGHT UP FIW TO 9 PPG FOR WELL KILL. CIRCUI_JkTED 9 PPG FIW TO KILL WELL FLOW. CHECK FLOW - JARRED UP ON HOWCO PACKER AT 250K - PACKER CAME FREE. BEGAN TO POH WITH TBG CONVEYED PERF ASSEMBLY. RIG NAME PLATFORM FI MIDDLE GROUND SHOAL LE~d PLATFORM UELL A24-O1LE WORK ORDER 723530 SIDE TRACK DRILLING FOREMAN: SELTZ RH . . SUEP! ALASKA DALLY DRILLING REPORT · PROG. DEPTH 11943 PRESENT DEPT~ FOOTAGE DRILLED SIZE OF LAST CSG DEP. OF LAST CSG WATER DEPTH /GALLOWAY DR PRESENT ACTIVITY: RIH WITH COMPLETION~STRING 5.000 11994 80- SUMMARY OF OPERATIONS (SHOW HOURS FOR EACH OPERATION) : 2.00 CONT. TO POH WITH SHOT PERF GUNS. TIME (HRS) CUM. ROT. HRS 270.50 ROTATING MI/D MOTOR TRIPPING 3.50 C&C 7.00 RF_JtMING SURVEYS JET REPAIRS FISHING NIP UP/DOWN /BOP/WN TESTING BOP /WH RUNNING CASING CEMENTING PICKUP/LAY DOWN DS INSPECT BNA RIG UP/TEAR DOWN WAIT ON WEATHER/MAT EVALUATION CORING OTHERS 13.50 PAGE 1 OF 1 4.50 RIH WITH SCRAP~ERS TO 10j010'. 1.50 CIRCULATE BOTTOMS UP VIA GAS BUSTER. 4.50 I .50 5.50 CHECK FLOW AND POH WITH SCRAPPERS. LAID DOWN 2 7/8 PAC TBG. CHANGED OUT BOP RAMS FROM 3.5 TO 2 ZL8 FOR PRODUCTION STRING. PERFORMED SUCCESSFULL BOP TEST. SOME PROBLEMS GETTING TEST PLUG~.TBG HANGER TO HOLD. .50 PREP TO RIH WITH PROD. EQUIPMENT. ~gTE: ~A]~X. COSTS H_j_IGH DUE TO__m!3,TgO W!RELINE COSTS AND $!46,300 COSTS FOR TBG CONVEYED PERFORATING. .50 ~/U 5" AND'7" TANDOM SCRAPPER ASSEMBLY. 3.50 HELD PRE-JOB SAFETY MEETING ON LAYING DOWN SHOT TBG CONVEYED PERF GUNS. LAID DOWN GUNS. TIME_I~RS) ____ CUM. ROT. HRS 270.50 ROTATING MUD MOTOR TRIPPING 11.00 C & C 1.50 REAMING SURVEYS JET REPAIRS FISHING NIP UP/DOWN /BOP/WH 1.50 TESTING BOP /WH 5.50 RUNNING CASING CEMENTING PICKUP/LAY DOUN DS 3.50 INSPECT BHA 1.00 RIG UP/TEAR DOWN WAIT ON WEATHER/MAT EVALUATION CORING OTHERS ELEVAT. KB TO MSL 116.0 DATE ~510~/9~ DIST. KB TO 8HF .. 38.4 DAY 45 · . NLTA LTH/YTD / EST. DAY 22 LTA LTH/YTD ___/__ DAYS +/- DAYS SINCE LAST LTA 761 LAST BOP TEST ~5/~/9~ LAST CSG TEST 04~/9~ BHA INSPECTION (CUM. ROT HRS) PP1 @ KILL SPEED 270 @ 30 PP2 @ KILL SPEED 760 @ 50 SUEPI ALASKA DAILY DRILLING REPORT PAGE 1 OF 1 RIG NAME PLATFORM FIEtD MIDDLE GROUND SHOAL LE PLATFORM UEL~ A24-O1LE UORK ORDER 723530 SIDE TRACK _ DRILLING FOREMAN: UELLS R V PRESENT ACTIVITY: TESTING WELLHEAD PROG. DEPTH 1-1943 ELEVAT. KB TO MSL 116.0 DATE P5/~/_~ PRESENT DEPTH DIST. KB TO BHF 38.4 DAY 46 .,.--..----- FOOTAGE DRILLED NLTA LTH/YTD / EST. DAY 22 SIZE OF LAST CSG 5.000 LTA LTH/YTD __/ DAYS +/- DEP. OF LAST CSG 11994 DAYS SINCE LAST LTA ~62 WATER DEPTH 80 LAST BOP TEST 05__5.5.5.5.5.5.5.~/95 LAST CSG TEST /GALLOWAY DR BHA INSPECTION (CUM. ROT HRS) PP1 a KILL SPEED 270 @ 30 PP2 @ KILL SPEED 760 a 50 SUMMARY OF OPERATIONS (SHOW HOURS FOR EACH OPERATION) : 9.50 HELD PRE-JOB SAFETY MEETING. RIH UITH PRODUCTION STRING AS FOLLOUS: WL REG_~:~/1.~95)-, 1JT. 2 )/8 4.7~ N-80 TB__G~.O~IS "XN" NIPPLE .~.37_~7~91~1.2._~5), 1 ~.T 2 3/8 TBG, BAKER "FH" PACKER wZRUP~ :(4.125L_..- 1.978/~3~5~), ! ~T~2. 3/8 TBG~ OTIS "X" NIPPLE (Z.375/1.875/1.!8), I JT 2 3.8 TBGz GLM #10 W~PU~S (~.8~ 1~.~01~)5.02), .~? JTS 2 3/8 EUE__ 8RD TBG, 2 ~/8,P)N X 2 ~/8 BOX CROSS-OVER.(3.668/1.995/1r61), 1 JT 2 7 8_~E8~D ~5# N-80 7BG, GLM #9 ~4__.7~0/2.34~/14.9~)~1~JTS 2 [BG~ GIM #8 (4.7~/2...3~/15.01), 17 JTS 2_7/8 TBG~ GLM #[. (4.75/2.3~[_ ~5.0),.. 17 JTS 2 7/8 TBG, GLM.#6 ~_.7E/2.347/14.99), 18 JTS 2 7/8, GLM #5 (~.7512.347/14.98), ~2 JTS 2 7/8, GLM #4 (4.7~34711~.99)~ ~.347~)~.85), 53 JTS 2 ~/8, GLM #). ~.7512.3~7/14~), 56 JTS._2 7/8, BAKER SS__SV_~/TLO'AND PU~S.(4.625/2.31_~:63), 8 JTS 2 7~8,_1 ~ 7/8 ~UP (10~44), 1 2 ?/~ PUP (8,3), AND TUBIng_ HANGER (2.441/1.15). PACKER IS SET UITH 30K SHEAR. 9 BANDS ON CONTROL LINE. UP WEIGHT 110K, DO~N WEIGHT. 95K. 6.50 LANDED TBG HANGER AND RU SLICKLINE. RIH AND SET TEST PLUG IN XN NIPPLE. PRESSURED TBG UP TO 3500# TO SET PACKER AT 9823~. PRESSURED CASING ANNULUS UP TO 1000# TO VERIFY PACKER SET. REMOVE TEST PLUG AND RD SLICKLINE. 8.00 INSTALL WELLHEAD BPV. REMOVE BOP~S AND OTHER ASSOCIATED EQUIPMENT. HELD PRE-JOB SAFETY MEETING. REMOVED UELLHEAD STACK AND INSTALLED TIME (HMS) CUM. ROT. HMS 27'0.50 ROTATING MUD MOTOR TRIPPING 9.50 C & C. REAMING S'URVEYS JET REPAIRS FISHING NIP UP/DOWN /BOP/WH 8.00 TESTING BOP RUNNING CASING CEMENTING PICKUP/LAY DOWN DS INSPECT BHA RIG UP/TEAR DOWN WAIT ON WEATHER/MAT EVALUATION CORING OTHERS 6.50 SWEPI ALASKA DALLY DRILLING REPORT RIG NAME PLATFORM FIE'n MIDDLE GROUND SHOAL LE PLATFORM "A" JEL~ A24-O1LE JORK ORDER 723530 ~IDE TRACK )MILLING FOREMAN: WELLS R V PROG. DEPTH 119~3 PRESENT DEPTH ~OOTAGE DRILLED : SIZE OF LAST CSG 5.000 DEP. OF L~ST CSG 11994 gATER DEPTH 80 /GALLOWAY DR PAGE 1 OF 1- ELEVAT. KB TO MSL 116.0 DATE DIST. KB TO BHF 38.4 DAY NLTA LTH/YTD __/__ EST. DAY LTA LTH/YTD / DAYS +/- DAYS SINCE LAST LTA 763 )RESENT ACT-IVITY: RIG RELEASE_5/lO/95. ;UMMARY OF OPERATIONS (SHOW HOURS FOR EACH OPERATioN) : .50 COMPLETE WELLHEAD INSTALLATION. TEST AP SP~[z AND WELLHEAD TO 5000#. 2.00 CIRCULATE HOLE WITH 8.5# FIW. LAST BOP TEST 95/~[95 LAST CSG TEST 04_~E/__~.E BHA INSPECTION (CUM. ROT HMS) PP1 @ KILL SPEED @ 30 PP2 @ KILL SPEED @ 50 2.00 RU SLICKLINE. RIH WITH GL VALVE AND SET IN GLM #10. RDWL. .50 REMOVE LANDING JT. ~U PROD TREE CAP AND RETURN WELL TO PRODUCTION. 1.00 REMOVE ASSOCIATED EQUIPMENT AND READY RIG FOR PLATFORM MOVE. RIG RELEASED 'FROM A24-OILE AT 12:00 P.M. TUESDAY 5-10-95 AND ACCEPTED ON A43-11LW. TIME.~RS~ CUM. ROT. HRS 270.50 ROTATING MUD MOTOR TRIPPING C&C 2.00 REAMING SURVEYS JET REPAIRS FISHING NIP UP/DOUN /BOP/WH .50 TESTING BOP /WH RUNNING CASING CEMENTING PICKUP/LAY DOUN DS INSPECT BHA RIG UP/TEAR DOUN WAIT ON WEATHER/MAT EVALUATION CORING OTHERS 3.50 Anadrill Schlumberger 07/11/95 Client .... : SHELL WESTERN E & P Field ..... : MIDDLE GROUND SHOAL ,Well ...... : A24-01LE Section at:, 91.83 Engineer..: BROWN / LEJEUNE Units ..... : FEET INC Computation...: Survey Date...: KB Elevation..: Reference ..... : Magnetic Dcln.: MINIMUM CURVATURE 07/11/95 116.00 ft JOB~35904/APE~723530 22 . 682 E S MEAS INCLN DIRECTION C DEPTH ANGLE AZIMUTH N 9960 32.41 346.18 3 10170 29.30 351.80 3 10222 29.50 342.70 N 10230 29.34 344.05 3 10276 28.70 352.00 RECORD OF SURVEY (Calculated from a tie-in station at 9960 MD) VERTICAL-DEPTHS SECTION RELATIVE-COORDINATES BKB SUB-SEA DISTNCE FROM-WELL-HEAD 8686.2 8570.2 2356.6 3710.2 N 2476.0 E 8866.5 8750.5 2332.4 3815.8 N 2455.2 E 8911.8 8795.8 2326.0 3840.6 N 2449.6 E 8918.8 8802.8 2324.8 3844.4 N 2448,5 E 8959.0 8843.0 2319.4 3866.1 N 2443.8 E Pg: 1 CLOSURE DL DISTNCE AZIMUTH /10 4460.5 33.72 0.00 4537.4 32.76 2.02 4555.3 32.53 8,59 4557.9 32.49 8.50 4573.8 32.30 8.50 3 10318 27.60 354.60 8996.0 8880.0 2316.5 3885.8 N 2441.5 E N 10346 28.14 0.78 9020.8 8904.8 2315.6 3898.9 N 2441.0 E 3 10363 28.60 4.40 9035,8 8919.8 2315.7 3907.0 N 2441.3 E 3 10386 30.20 9.30 9055.8 8939.8 2316.7 3918.2 N 244.2.7 E 3 10414 30.70 13.60 9079,9 8963,9 2319.1 3932.0 N 2445.5 E N 10447 31.55 16.24 9108.2 8992,2 2322.~ 3948.5 N 2449,9 E 3 10449 31.60 16.40 9109.9 8993.9 2323.2 3949,5 N 2450,2 E 3 10461 31.80 19.90 9120.1 9004.1 2325.0 3955.5 N 2452,2 E 3 10498 31.60 32.50 9151.6 9035.6 2332.9 3972.9 N 2460.7 E 3 10556 29.50 42.40 9201.6 9085.6 2350.0 3996.3 N 2478.5 E 4589.2 32.14 3.92 4600,0 32.05 10.48 4607.0 32.00 10.48 4617.2 31.94 12.56 4630.5 31.88 7.98 4646.8 31.82 4.87 4647,8 31.81 4.87 4654,0 31,80 15.t 4673.2 31.77 17.&. 4702.5 31.81 9.39 N 10578 29.66 45.33 9220.7 9104.7 2357.3 4004.1 N 2486.0 E 3 10609 30.00 49.40 9247.6 9131.6 2368.3 4014.5 N 2497.4 E 3 10629 30.10 51.50 9264.9 9148.9 2375.8 4020.9 N 2505.1 E 3 10652 31.60 54.30 9284.7 9168.7 2385.0 4028.0 N 2514.5 E 3 10677 32.70 57.20 9305.8 9189.8 2395.7 4035.5 N 2525.5 E 4713.1 31.84 6,62 4727.9 31.89 6.62 4737.4 31.92 5.28 4748.4 31.97 9.03 4760.6 32.04 7.58 ^Station Types: 3/MWD N/INTERPOLATED ***Grid and magnetic, corrections have been applied to these surveys*** (Anadril (c)95 A2401LED B1.52 11:15 AM 2) A24 - 01 LE MEAS INCLN DIRECTION DEPTH ANGLE AZIMUTH 10700 33.80 60.00 10736 36.90 65.00 10761 38.60 70.20 10783 40.50 74.90 10803 41.80 77.50 ~0831 44.50 80.10 10869 47.60 83.20 10899 49.60 85.30 10936 52.60 89.50 10972 56.20 92.30 10991 58.40 92.3 11035 63.70 93.5 11048 64.13 93.8 11065 64.70 94.4 11095 65.30 95.1 RECORD OF SURVEY (Calculated from a tie-in station at 9960 MD) t 11125 66.40 95.1 ~ 11155 66.50 94.4 / 11192 66.80 93.7 _ ~1222 67.40 93.7 302 70.20 93.7 VERTICAL-DEPTHS BKB SUB-SEA 11345 71.13 92.4 11440 73.20 89.6 11480 74.04 89.6 11622 77.00 89.6 11994 77.00 89.6 'Station Types: 3/MWD N/ ~**Grid and magnetic corre SECTION RELATIVE-COORDINATES DISTNCE FROM-WELL-HEAD 9325.1 9209.1 2406.3 4042.1 N 2536.3 E 9354.4 9238.4 2424.4 4051.6 N 2554.8 E 9374.2 9258.2 2438.4 4,057.4 N 2568.9 E 9391.2 9275.2 2451.6 4061.6 N 2582.3 E 9406.2 9290.2 2464.3 4064.8 N 2595.0 E 9426.7 9310.7 2482.9 4068.5 N 2613.8 E 9453.0 9337.0 2509.8 4072.4 N 2640.9 E 9472.9 9356.9 2532.1 4074.7 N 2663.3 E 9496.1 9380.1 2560.8 4076.0 N 2692.0 E 9517.1 9401,.1 2590.1 4075.5 N 2721.3 E 0 9527.3 9411.3 2606.1 4074.8 N 2737.2 E 0 9548.6 9432.6 2644.6 4072.9 N 2775.7 E 9 9554.4 9438.4 2656.2 4072.1 N 2787.3 E 0 9561.7 9445.7 2671.5 4071.0 N 2802.6 E 0 9574.4 9458.4 2698.7 4068.8 N 2829.7 E 0 9586.6 9470.6 2726.0 4066.3 N 2857.0 E 0 9598.6 9482.6 2753.5 4064.1 N 2884.4 E 0 9613.3 9497.3 2787.4 4061.7 N 2918.3 E 0 9625.0 9509.0 2815.1 4059.9 N 2945.9 E 0 9653.9 9537.9 2889.6 4055.1 N 3020.3 E 1 9668.1 9552.1 2930.2 4052.9 N 3060.8 E 0 9697.2 9581.2 3020.6 4051.3 N 3151.2 E 0 9708.5 9592.5 3058.9 4051.6 N 3189.6 E 0 9744.0 9628.0 3196.3 4052.6 N 3327.0 E 0 9827.7 9711.7 3558.5 4055.1 N 3689.5 E INTERPOLATED ctions have been applied to these surveys*** Page 2 07/11/95 CLOSURE DISTNCE AZIMUTH 4771.9 32.11 4789.8 32.23 4802.3 32.34 4813.0 32.45 4822.5 32.55 4835.8 32.72 4853.8 32.96 4867.9 33.17 4884.7 33.44 4900.5 33.73 DL /loo 8 .21 11.77 14 .43 16.11 10.74 11.54 10.05 8.49 11.99 11.83 4908.9 33.89 11.58 4928.8 34.27 12.28 4934.7 34.39 4.29 4942.5 34.54 4.29 4956.0 34.82 2.91 4969.7 35.09 3.67 4983.6 35.36 2.16 5001.3 35.70 1.92 5016.0 35.96 2.00 5056.3 36.68 3.50 5078.8 37.06 3.56 5132.6 37.88 3.56 5156.4 38.21 2.09 5243.3 39.39 2.09 5482.4 42.30 0.00 April26, 1995 Shell Western E&P Inc. An affiliat~ of Shell O~ Company P. O. Box 576 Houston, TX 77001 Mr. Larry Grant Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Grant: SUBJECT: FORMATION TOPS PICKS FOR THE SWEPI MGS A-24-01LE, MIDDLE GROUND SHOAL FIELD, KENAI BOROUGH, ALASKA Here is a list of formation tops encountered in the SWEPI MGS A-24-01LE (APl# 50-733-20258-01), as required by the AOGCC. Please note that this well was drilled through the overturned limb of the Middle Ground Shoal anticline, so the second set of Hemlock formation tops were encountered in reverse order. A-24-01LE {I~ = 116') Approximate Formation Top MD TVD Subsea HD 10,098' 8,804' -8,688' HE 10,120' 8,823' -8,707' HF 10,146' 8,845' -8,729' HI 10,210' 8,901' -8,785' HK 10,263' 8,947' -8,831' I-IN 10,426' 9,089' -8,973' HR 10,685' 9,312' -9,196' HR(overturned) 11,037' 9,549' -9,433' HN 11,334' 9,663' -9,547' HK 11,549' 9,725' -9,609' HI 11,610' 9,740' -9,624' HF 11,673' 9,752' -9,636' HE 11,715' 9,759' -9,643' I-ID 11,731' 9,762' -9,646' HC 11,866' 9,784' -9,668' TD 11,994' 9,805' -9,689' If you have any questions, I can be reached at (713) 544-2389. Very truly yours, Maria A. Balzarini Senior Petrophysical Engineer RECEIVED APR 2 8 1995 Alaska Oil & Gas Cons. CommissiOn Anchorage April 26, 1995 Shell Western E&P Inc. An ~t~e of Sh~ll Off Company P. O. Box 576 Houston, TX 77001 Mr. Larry Grant Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 SUBJECT: LOG DATA FROM SWEPI MGS A-24-01LE, MIDDLE GROUND SHOAL FIELD, COOK INLET, ALASKA Enclosed please find the following log data from the SWEPI MGS A-24-01LE well in Middle Ground Shoal Field, Kenai Borough, Alaska (API# 50-733-20258-01): ~ 1 BLP Phasor Induction - Sonic - Density - Neutron - Gamma Ray log ~ 1 BLP Neutron - BHC Sonic - Lithodensity - Gamma Ray log ~ 1 BLP Array Induction Imager - 1 Foot Resolution log ~x. 1 BLP Array Induction Imager - 2 Foot Resolution log x'N-'l BLP Array Induction Imager - 4 Foot Resolution log ~1 Sepia Phasor Induction - Sonic - Density - Neutron - GR log "-x~ 1 Sepia Neutron - BHC Sonic - Lithodensity - Gamma Ray log "~ i., Sepia Array Induction Imager - 1 Foot Resolution log '~-- 1 Sepia Array Induction Imager - 2 Foot Resolution log · ~ 1 Sepia Array Induction Imager - 4 Foot Resolution log xI LIS tape DITE/AIT/SLT/LDT/CNL/GR/AMS Tape Listing DITE/AIT/SLT/LDT/CNL/GR/AMS '~.~ 1 List of Formation Tops Please sign one copy of this letter and return to me at the above add,si. C E IV E D Very truly yours, Mafia A. Balzarini Senior Petrophysical Engineer Alaska 0it & 6as 60ns. Commission Date: April 26, 1995 Shell Western E&P Inc. P. O. Box 576 H(mston, TX 77001 Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Grant: FORMATION TOPS PICKS FOR THE SWEPI MGS A-24-0 ILE, MIDDLE GROUND SHOAL FIELD, KENAI BOROUGH, ALASKA Here is a list of formation tops encountered in the SWEPI MGS A-24-01LE (API# 50-733-20258-01), as required by the AOGCC. Please note that this well was drilled through the overturned limb of the Middle Ground Shoal anticline, so the second set of Hemlock formation tops were encountered in reverse order. A-24-01LE (KB = 116') Approximate Formation Top MD TVD Subsea HD 10,098' 8,804' -8,688' HE 10,120' 8,823' -8,707' HF 10,146' 8,845' -8,729' HI 10,210' 8,901' -8,785' HK 10,263' 8,947' -8,83 I' HN 10,426' 9,089' -8,973' HR 10,685' 9,312' -9,196' HR (overturned) 11,037' 9,549' -9,433' HN 11,334' 9,663' -9,547' HK 11,549' 9,725' -9,609' Id/ 11,610' 9,740' -9,624' HF 11,673' 9,752' -9,636' HE 11,715' 9,759' -9,643' HD 11,731' 9,762' -9,646' HC 11,866' 9,784' -9,668' TD 11,994' 9,805' -9,689' If you have any questions, I can be reached at (713) 544-2389. Very truly yours, Senior Petrophysical Engineer MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: David Jo~ Chairma~ DATE: April 14, 1995 THRU: Blair Wondzell, ~ P. i. Supervisor ~/'¢~' F R O M: Bobby Fost eer~-~.~. S UBJE CT: Petroleum Inspector FILE NO: AV31DNCD.doc BOPE Test -Inlet rig A Shell - MGS - A24-01LE PTD # 95-~(~54---~ / "7___ MGS Field Friday, April 14, .1995: i traveled this date to Shell's Cook Inlet Platform A ,~nd witnessed the weekly BOPE test. As the attached AOGCC BOPE Test Report shows there were no failures. All equipment functioned and tested properly. The rig was clean as could be expected since they are using oil base mud. All other equipment seemed to be in good working order. Summary: I witnessed the weekly BOPE test on Inlet Drilling Rig A - Test time 3 hours - no failures. Attachment: AV31DNCD.XLS STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report OPERATION: Drig: X Workover: DATE: Drlg Contractor: INLET DRILLING Rig No. A PTD # 95-0054 Rig Ph.# Operator: SHELL WESTERN Rep.: R. V. WELLS Well Name: A24-OILE Rig Rep.: J. DODGE Casing Size: 7" Set @ '10,888' Location: Sec. '11 T. 8N R. 13W Meridian S Test: Initial Weekly X Other 4/'14/95 776-5756 Test MISC. INSPECTIONS: Location Gen.: OK Housekeeping: OK (Gen) PTD On Location OK Standing Order Posted OK Well Sign OK Drl. Rig OK Hazard Sec. OK FLOOR SAFETY VALVES: Upper Kelly / IBOP Lower Kelly / IBOP Ball Type Inside BOP Quan. Pressure P/F I 500/5,000 P 1 500/5,000 P f 500/5,000 P I 500/5,000 P BOP STACK: Annular Preventer Pipe Rams Lower Pipe Rams Blind Rams Choke Ln. Valves HCR Valves Kill Line Valves Check Valve MUD SYSTEM: Trip Tank Pit Level Indicators Flow Indicator Meth Gas Detector H2S Gas Detector Quan. Test Press. P/F Test I 300/3,000 P Pressure 500/5,000 '1 500/5,000 P 500/5,000 P '1 500/5,000 P '1 5O0/5, OO0 P 'I 500/5,000 P 2 500/5,000 P I 0 P CHOKE MANIFOLD: No. Valves 13 No. Flanges Manual Chokes Hydraulic Chokes 1 32 500/5,000 1 P/F P P P Functioned Functioned ACCUMULATOR SYSTEM: System Pressure Pressure After Closure Visual Alarm 200 psi Attained After Closure 0 minutes 41 sec. NOTE System Pressure Attained 2 minutes 39 sec. Blind Switch Covers: Master: YES Remote: YES Nitgn. Btl's: 4 ~, 2700 2,850 P 1,550 P Psig. Number of Failures: 0 ,Test Time: 3.0 Hours. Number of valves tested 2'/ Repair or Replacement of Failed Equipment will be made within 0 days. Notify the Inspector and follow with Written or Faxed verification to the AOGCC Commission Office at: Fax No. 276-7S42 Lnspcctor North $1ope Pager No. 659-3607 or 3687 If your ca~l is not returned by the inspector within 12 hours please contact the P. I. Supervisor at 279-1433 REMARKS: GOOD TEST NOTE: THE GAS ALARMS WILL BE TESTED LATER TONIGHT BY THE ONDUTY ELECTRICIAN AND A COPY OF THE RESULTS WILL BE FAXED TO THE AOGCC OFFICE. Distribution: orig-Well File c - Oper./Rig c- Database c - Trip Rpt File c- Inspector STATE WITNESS REQUIRED? YES X NO 24 HOUR NOTICE GIVEN YES X NO Waived By: Wrtnessed By: BOBBY D. FOSTER F1-021L (Rev. 12/94) AV31DNCD.XLS ALASKA OIL AND GAS CONSERVATION COMMISSION TONY KNOWLE$, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 February 14, 1995 G S Nady, Mgr, Asset Admin Shell Western E&P Inc P O Box 576 (WCK 5237) Houston, TX 77001-0576 Re: Well # Company Permit # Surf Loc Btmhle Loc Middle Ground Shoal A24-01LE Shell Western E&P inc 95-12 1564'FSL, 378'FEL, Sec 11, T8N, R13W, SM 11,943'MD-KB, 0'FNL, 3298'FWL, Sec 12, T8N, R13W, SM Dear Mr Nady: Enclosed is the approved application for permit to re-drill the above referenced well. The permit to re-drill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting re-drilling operations until all other required permitting determinations are made. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25.035. Sufficient notice (approximately 24 hours) of the BOPE test performed before drilling below the surface casing shoe must be given so that a representative of the Commission may witness the test. Notice may be given by contacting the Commission at 279-1433. Chairman , ~ BY ORDER O~SION jo/encl c: Dept of Fish & Game, Habitat Section - w/o encl Dept of Environmental Conservation - w/o encl STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 la. Type of work Drill ~ Redrill ~ lb. Type of well. Exploratory r----JStratigraphic Test ~ Development Oil r-z-] Re-Entny ~--~Deepen ~ ServiceF~1 Development Gas[~1 Single ZoneF--1 Multiple Zoner--m 2. Name ~)f Operator 5. Datum Elevation (DF or KB) 10. Field a~d Pool Shell Western E&P Inc. 116' KB feet FIIDDLE GROUND SHOAL 3. Address (.wc~ ~,2_'~'1') 6. Property Designation P.O. Box 576, Houston, TX 77001-0576 ADL 18754 ~'~ 4. Location of well at surface P~.&T F A)/..E:~ 4~ coNC~ ~-E~ 7. Unit or property Name 11. Type Bond (s~,2o~c25:o25) 1564' FSL & 378' FEL Sll, T8N, R13W, S.N. NIDDLE GROUND SHOAL BLANKET At top of productive interval 8. Well number Number 9960' FiD-KB; 7' FNL & 2098' FWL S12, T8N, A24-O1LE 400 HR 7522 At total depth P.,~3w, s. ~. Amount 9. Approximate spud date 11,943' FiD-KB; O' FNL & 3298' FWL S12, TSN $200,000 A,\3w~ s.~. 2/20/95 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (UD a,d TVD) property line 1982 feet 1100 feet 3746 11,943 FiD feet 16. To be completed for deviated wells 17. Anticipated pressure (s, 2o sc 25.o3~ (e × 2)) Kickoff depth 9960 feet Maximum hole angle 70 o Maximum surface 1531 psig At total depth (TVD) 5104 psig 18. Casing program Setting Depth s~ze Specifications Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 6" 5" 18# N80 STL 3343' 9200' 8060' 11943 9816 250 SX 19. To be completed for Redrill, Re-entry, and Deepen Operations Present well condition summary RECEIVED Tot,al depth: measured 10,900 feet Plugs (measured) true vertical feet jA~']. 2 6 1995 Effective depth measured 10,569 feet Junk (measured) &!;S~, 0il & Gas Cons. 60ramission true vertical feet Anchor; Casing Length Size Cemented Measured depth True vertical depth Structural Conductor 370' 20" 370' 370' Surface 2010' 13-3/8" 1300 SX 2010' 1830' Intermediate Production 10,799' 7" 2100 SX 10,799' 9396' Liner Perforation depth: measured 9663' - 10,534' true vertical 8437' - 9170' 20. Attachments Filing fee r~ Property platr'x'~ BOP Sketch~ Diverter Sketch E~] Drilling program r~ Drilling fluid program nX-1 Time vs depth plot E~] Refraction analysis E] Seabed report [--] 20 AAC 25.050 requirements 21. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed('t .'~'~(~ ~,-~/fy( G.S. NADYTitle FiGR - ASSET AD"IN. Date 1/19/95 Comission Use Only Permit Number IApi number ! Approve[ dat.e , ISee cover letter I 5o- ~,.e,~- 2_ c~ 2._ 5' ¢- ,o Yi 0¢0 / / ~//c~ ~-- Ifo.r other requirements COnditions of approval SamPles required [--~ ;~es~;;i~ No Mud icg required ~ Yes ~ No Hydrogen sulfide measures F~ Yes ~ No I~irectional survey required ~ Yes F~-]' No Required working pressure f(~J~ri~J gT~ll~ ~87 3M- ~ SM- ~IOM- ~ 15M Other: David W. Johnston byorderof / Approved by Commissioner the commission Date 2. Will t()CA'I'I()N I"'IAT MII)I)I t (:~It(.)UND .':.;I'IAL F'IEI I') . A PI A"I'FORM (3OO1< INI t,'1, AI'A~-~KA WEt,L.- A24--C)1 l.t.,. .SU I~1,' ACE.. I..C)CATION . '. 1~6.'~ I-%1 3 1P~() F'FI ,-~ 1 2 1¢)8N Itl ,SW "' KI)I' 1 1 6' M~..;I 2 A41 .... 11RLND~ 11 A52 t1.(; A32--11RF' A41 ........... K'"i 3 111%r) A54 A31 .. A31 14IWl) .... .-- - A13 A44 A 12A-. (:)t G Atl (.)1(,; 01LND . 'A22-01[; . ,. · , . · ' A?'J ()1 RI.K; " A33.....--. 0.1 C '; '3-01'0" :'."~AU~F:'r t1~' 10864. M[; 9416TVD IA14 -01 300 FSL 29.7,0 FEI. S.Oi 'I'OBN R 16W SM ,, '.5'EC 01 TC')B'N R'I iCW' SEWARD MERIDIAN .,A24 .- 1DLE "1ARG61//2/I~HI. 11943'MD 9'816'1V0 b2'/91"SL 1980 FEI. Sl? TO~NR15W ,SM 1 A24' ()il fl~ 12 ~l, ' :'Ti~' '(tN' '/KOP 9960.MP. 8686 'IVD 52~5:FS1' 5180 FI:.L $'12'~O8'N RI,,.'.'.tW SM 12C .R'E"¢EIVED A13 12(';, ' jAN 2 6 1995' _. ........... '"' A23-12C ..... - Alzska Oil & Gas Cons. Commission ,., :An~hora ':" · A15-12RI}G "' :' , , , 12 AI1. 15R1G 1,5 A22. 14 .. IJ:\DC\MAI L~i\filll'l I \APl A1 .rlw2 JANUARY I el, 1 .~fi5 A22 14 A55. 1,10 / A34 14R.1G' /-' . A34 14(; (,'~" [,~ 1,.', I (, 1 4 15 MIDDLE GROUND SHOAL WELL NO. A24-01LE WELL PROGRAM Middle Ground Shoal (MGS) A24-01LE will be a redrill of existing well A24-01. The objective is the Hemlock reservoir. The well will be drilled directional out of the existing 7" casing through the Hemlock to a TVD of 9,816'. KOP will be at the top of the Hemlock. The well will be completed with a 5" cemented liner across the Hemlock reservoir. The existing perforations in the Hemlock will be abandoned by setting a cement plug across the perforations from TD to the top of the Hemlock. The existing perforations above the Hemlock will be shut off by cementing the 5" to 9,200'MD. WELL: LOCATION: OBJECTIVE: EVALUATION A24-O1LE PLATFORM A, LEG 4, CONDUCTOR 28 1,563'FSL 378'FEL Sll TOBN R13W SM HEMLOCK GEOLOGY DRILLING PROGNOSIS FIELD: KB: MIDDLE GROUND SHOAL 116' DRILLING LOGS MUD SIGNIFICANT LOGGERS FORMATIONS III MD (TVD) 370' 2,010' (1,830') HOLE SIZE CASING MUD DIRECTIONAL PROGRAM PROGRAM 20" I 13 3/8" 7II i DRILLPIPE CONVEYED LOGS AMS GR CAL LDT DITE HEMLOCK HC HEMLOCK HE HEMLOCK HK HEMLOCK HN HEMLOCK HN HEMLOCK HK HEMLOCK HE HEMLOCK HC TD 9,200' (8,060') 9,960' (8,686') -- 11,943' (9,816') 6I' Sm' CEMENTED OIL BASE BUILD & MUD TURN TO 70 DEG S70E EXPECTED MUD WEIGHT 10.0 PPG MIDDLE ~ROUND SHOAL A24-01LE DRILLING FLUID PROGRAM The 6" hole will be drilled using an oil base mud. The anticipated mud weight is 10.0 ppg. EXPECTED PRESSURES The maximum expected pressure gradient is 0.52 psi/ft. The maximum expected bottom hole pressure is 5,104 psi at 9,816'TVD. The expected maximum surface pressure with an oil fluid column and the well shut in is 1,531 psi. CASING PROGRAM A 6" hole will be drilled out of the existing 7" casing to TD. 5" 18#/ft N80 flushjoint liner will be run to TD and hung at approximately 9,200'MD. The production liner will be perforated. A RECEIYEE) dAi'~. 2 (5 ~,9c35 & Gas Cons. Commission Anchor;.,. 2. 3. 4. 5. · · 8. 9. 10. 11. 12. 13. 14. DESCRIPTION SUMMARY OF PROPOSAL MIDDLE GROUND SHOAL A24-01LE Move to A24-01 (leg 4, conductor 28) and rig up. Kill well· Nipple up 5,000 psi BOP stack and test. Pull tubing and packer completion equipment. GIH with bit and scraper and clean out to TD at approximately 10,569'. Set a cement plug across the Hemlock perforations from TD to 9,500'MD-KB. GIH and clean out cement to 9,966'MD-KB. Use wireline and GR to set a bridge plug at 9,966'MD-KB. Set whipstock at 9,966'MD and sidetrack. Directional drill to ll,943'MD-KB using a 6" hole. Final hole angle will be 70 degrees in a S70E direction. Log. Run a 5" production liner to TD and hang off at 9,200'MD-KB. Cement liner. (Liner will shut off existing perfs from 9,960'MD-KB to 9,663'MD-KB.) Perforate. Run packer and tubing. (Packer at approximately 9,800'MD.) RECEIVED ,~/~tJ_ 2 6 i995 Oil & Gas Cons, Commission .Anchor;. Anadri 11 Schlumberger Alaska Di strict 1111 East 80th Avenue Anchorage, AK 99.518 (907) 349-4511 Fax 349-2487 DIRECTIONAL WELL PLAN for SHELL WESTERN E & P INC Well ......... : A24-01LE (P03) Field ........ : MIDDLE GROUND SHOAL Computation..: MIRIMU~4 CURVATURE Units ........ : FEET .~rfa~e Lat..,: 60.79561556 N Surface Long°: I51,49557121 W LOCATIO~ - ALASKA Zone: 4 X-Coord Y-Coord Legal Description Surface ...... : 1563 FSL 378 FEL Sll T08N R13W SM 232837.75 2485780.15 Tie~in/KOP...: 5273 FSL 3180 FEL S12 T08~ R13W SM 235397.58 2489432.91 Target ....... : 300 FSL 2930 FEL S01 T08N R13W SM 235654.51 2489733.92 BHL .......... : 5279 FSL 1980 FEL S12 T08~ ~13W SM 236597.41 2489412,35 PROPOSED WELL PROFILE Prepared ..... : 01/13/95 Section at...: 110,17 KB elevation.: 116.00 ft Magnetic Dcln: 22,682 E Scale Factor.: 0.9999.8122 ANADRILL AKA~DPC FEASIBILITY PLAN NOT APPROVED FOR EXECUTION PLAN 3 '1 STATION IDEtCT I FI CAT I ON TIE-IN / KOP 10/100 MEAS INCLN DIRECT ION VERT- DEPTHS SECT RELATIVE- COORDINATES DEPTH AN~LE AZ IMUT~ BKB SUB- S DIST FROM-THE - WELLHEAD 9960 32.41 10000 29,91 END OF 10/100 CRV~i 10010 29.34 START 10/100 CRV~2 10148 29.34 10200 27.16 ~'~- 10300 25.39 ~ .~ 10400 27.18 ~ ~ '~ ~} 10600 38.54 ~ ~ ~' ~ 10700 46 23 ~ Z080O 5~ .52 T~GET ~ ~-~ 10864 60.00 ' ~ ~ 10900 61.~0 ' , ~ ll000 64.68 STATE-PLANE TOOL DL/ X Y FACE I00 346.18 8686 8570 1045 37~0.21 N 2475.99 E 235397.58 2489432.91 131L <TIE 340,14 8720 8604 1033 3730.01 N 2470.04 E 235392.08 2489452.84 126L 10.00 338.51 8729 8613 1030 3734.59 N 2468.31 E 235390.46 2489457.46 10-~00 338.51 8849 8733 985 3797.34 N 2443.60 E 235367.19 2489520.75 llgR 0.0~ 348.60 8895 8779 970 3821.05 N 2436.52 E 235360.65 2489544.62 ll0L 10.0~ · 10.96 8985 8869 955' 3864.58 N 2436.09 E 235361.21 2489588.15 90R 10o00 33 31 9075 8959 956 3904-.82 ~ 2452 75 E 235378 78 2489627 99 70R 10 00 5i 27 9162 9046 975 3940 53 N 2486 00 E 235412 83 2489662 94 54R 10 00 64 33 9244 9128 1011 3970 6~ N 2534 82 E 235462 33 2489691 93 43R 10.'00 73 86 9318 9202 1062 3994 24 N 2597.74 E 235525 77 2489714 08 36R 10 00 81.13 9382 9266 1126 4010.59 N 2672.84 E 235601.23 2489728.72 32R 10.00 .... 85.00 9416 9300 1174 4017.00 N 2726.00 E 23565~.51 2489733.92 73R 1~.00 88' 9~. ..9~3~ ..93~8 · .1203 ..... 40~8,65 N. '275~'.'5'6-E 235686..1~ 248'9.7.34.85 71R 10~.00 99.47 9480 9364 1289 4011.99 N 2846.13 E 235774.50 2489726.17 67R 10.00 {Anadm~l {c,%95 A2401LEF Bi._~2:2:26 PM 1} A24-O1LE (PO3} STATION IDENTIPICATiO~¢ 11100, 68.96 ~ND OF 10/100 CRV~2 11109 69.38 ~ARGET ~2 11943 69 38 11943 69.38 PROPOSED WELL PROFILE 0~I~3195 STATE- PLANE 109 30 9519 9403 1380 3989,~6 N 2934.98 E 235862.8~ 2489701.23 110.17 9522 9406 1388 3986.20 N 29~2.96 E 235870.71 2489698.19 110.17 9816 9700 2169 3717.00 N 3676.00 E 236597.41 2489412.35 110.17 9816 9700 2169 3717.00 N' 3676.00 E 236597.41 2489412.35 Pa~e 2 MEAS INCL~/ DIRECTION VBRT-D~PTHS SECT DEPTH ANGLE AZIMUT~ BKB SUB-S DIST RELATIVE COORDINAT ' = ..................... - ES PROM-T~E-WEL/2~EAD TOOL DL/ FACE 63R 10.00 10.00 , 0.00 0'00 AN'ADRILL AKA-DPC FEASIBILITY PLAN NOT APPROVED FOR EXECUTION PLAN ~~3__ ~Oadrlk (0) 95 A2401L-~.3 SHELL WESTERN E'"8 ..... P 'INC ............. ' I llIllll I .......I II IIIII I ' /~"~'-'0 ] LE ('PO3) VERTICAL SECTION VIEW ___ ........... iii i i ..... Section ~t: ~10.17 TVO S¢818 ' ~ inch = 1200 feet · Dep Scale.' ~ inch = i200 feet · Drawn ' 0~/~3/95 /nad/*] ] ] Sch]umber'gen Marker Identification . NO 8K8 SECTN INCLN AJ TIE-IN / KOP I0/t00 9960 8686 1045 32.41 8) ENO OF lO/~O0 CRV#i tOOlO 8729 1030 29.34 C) START 10/100 CRV#8 10~48 8849 985 29.34 D) TARGET #! 10864 9416 1174 60,00 E) END 0¢ lO/lO0 CRV#2 lllO9 95~2 1388 69.38 F) TARGET t~ 1~9~3 9816 ~189 69.38 G) TO 119~3 9816 2169 69.38 ~TION , ,, - i200 -600 0 600 1200 ~drjll [6!.~3 A240~ .L¢:~ ~,~ 12:~ ~ ~}-. - , l~oo a~oo 3ooo ~6oo .._ Sec.ti,,o,n.. _Departure , _ . ! :' 4200 4800 .. · . · . . 54O0 6000 I 66OO 72.00 ill I......... SHELl"_ NESTERN __ Marker Ident if~cat ~on ~ ELK8 SECTN INCLN A~ IlE-II~ / KDP lO/lO0 99~ B~B 1045 32.41 B~ E~ OF ~O/~O0 C~V~ ~0010 8729 103~ 29.3~ CJ SIARI ~0/100 CRV~2 ~0148 6849 985 29.34 81 lARGEr ¢1 30864 9416 1174 60.08 E] END ~r tO/~O0 CRV¢2 I~109 ~22 1386 69.38 F) [AR~T ~2 ~i943 9B~6 2169 69.38 6) fD ~194~ 9B~6 2~69 69.3B E,~, P ]:N'C. ....... , I . · LI! t ti _1 _. I Anadri ] l Schlumberger i il iii A24-01LE (P03) VERTICAL SECT_ION VTEW Section at: }i0.17 TVD Scale.: 1 inch = 300 feet Oep Scale.: ~ inch = 300 feet Drawn ..... :01/23/95 ' " -DP-C i-- -' ~ ' ' ' LC ' / I ! FE/,S1BI'_tTk' PLAN ' ' EXB]UT ON ~ ' ......... P-~ P~N- , ~ ~ ~ ~ ~ ~ " i ¢ , i ~ I --~ ~ - ~ , . { I ~~ ...... ', .% i ', - ~, ~ ............ ~ ............... , ~ " , I ....... :- · · I I ; ' ~ 600 7DO gO0 ~050 1~0 t350 ldO0 ~650 tSO0 ~950 2t00 2250 2400 2550 2700 2850 3000 3~5D 3300 .............. sec[ ion DeParture .................. A24'-'O. ILE, (PO3) ..... · .... PLAN VIE,W CLOSURE ' 5228 feet at Azimuth zl4.68 DECL [NATI ON ', 82 , ~82 E ii "i,~ :i ,i i ,-4600 SCALE ' I inch = 200 fee[ ! ,Ii I ~ ',' FEASIBILITY ~PLAIW -- , i ........ ] i I Marker t~ent~fic~t~on t. ID M/S E/N !I NIAT ~DDI)~N/~ KlqD .. 4400 F) 14AGE] ¢2 f~94~ 37~7 3676 ~ ...... , ....... - ~ ~ ,6t fO tt943 37~7 . ~676 i I .......... i"~ .............. : ~ 4~00 ........ ~: ................................. t.. -3900 ~ ..... ('~ y .- : [ ' , ~ ~ ....... : " '~ ...................... 3700 ~, ~ .' : ' ~I I 3600 '- ~ % " ~ ' , ,. -----' ......... ~i ,, -- I .................................. , · --35~0 2000 2100 2200 2300 2400 2500 8600 2700 2800 2900 3000 3100 3200 3300 3400 3500 3600 3700 EAST -> .... , , ~ , , ,~,, , ,,,,,, ,,, ,= , [~adrJ]i [C]93 ~,24DJ~_E:~ 8].-r'~ 12:29 i ---immm'i I .............. mill I i ...... i m MO N/S 99~0 37~0 ~00~0 3?35 i0~,~8 3797 i0864 40t7 t ~ t09 3986 t i943 ' 37i7 3B76 i1943 3717 3B76 - .. __ ANADRILL ' AKA-DPC FEASIBILITY PLAN NOT APPROVED FOR EXECUTION PLAN # .~ _ -- .... ~ ............ :, Marker Identi flcation A) TIE-IN / K0P 10/100 B) END OF I0/~Q0 CRY(! C) ST/~RT 10/10O CRV~2 O) TARC-ET ~ 1 E) END OF JO/lO0 C~W~ F) TAAGET ~2 G) TO .......... SH'EEL WESTERN'" EIi ' i I~ i i , I,~i .... INC ........ :, .i iii A24-0 ~444 ~726 2943 CLOSURE ..... DECLINATION.: !SCALE .......: DRAWN ....... : (PO3) PLAN VI£~ 5228 feet at Azimuth 4~1.68 22.582 E ~ inch : 800 feet 01/13/95 ~nadr. i ll Schlumberger 400 0 400 800 i200 iG00 ~000 2400 2800 3200 3600 4000 4400 4800 52,00 ,<- WEST ' EAST -> : ' ; : : --mi .... i ...... .;!- . ~ ..... - .: .:. :: . -.. '-. : : : .. :' ~ · .! HOLE 5000 PSI STACK TOP OF DER~CK FLOOR BOI/OM OF ROTARY BEAM FILL UP LINE !NIPPLE{ PRIER 5ooo PS[ i ( · BLAND RAM S000 PSI PIPE RAM 5OO0 PSI 2-1/16' ~ LINE RIG CELLAR FLOOR 13-.5/8- 5000 PSI FLANGE SPOOL · 13-.5/8' 5000 Pb-'I 3- !/8- CHOKE I_PtE ,, t3-5/8' 5000 PSI F'L~GE I __ wE~ ROOU FLOOR 5000 / ~ ~3-5/8' 50~ P~ F'I..ANCE 1 DSA / ~7 1.~/16- 5000 P~I FI_./dqGE ' ~ PSl FLANGE SHELL MINIMUM BOP STACK REQUIREMENTS , M~n. No. ~ Ilem I.D. Nominal 1 Flowline ~ --'~" 2 FiLl u,p Line 2" 3 Orillin9 Nipp, le ..... 4 Annular Preventer 5 Two t~ngle or on~ dual hydru~lically oullelt .. ? Ga~¢ Valve 3 1/8" ............... ~"- G~le Valv~ Power 0~taled 3 1/8': ' g "C,A,' ~0'cFok~ ~;;i~old ' ~-'" .... ........ 0 Gate Valve 2.1/16" 11 C~tCk V~lv~ .......... ~ 1/1'6"' .... fJ .... ~in~ S~o'ol ........ ................ 14 V~lves Gai~ 1 13/16" i~ c'0~pf.nf'P','b~'~'.~,'~.~ co~g'~c~, ....... ) Kill.l!~~ lg~i9~d pump manilold "~'"' ...._ ~8 ~ 2"x 2"X 2'~c,~s~ NOTE' Add, Well Conltol M~null, Ap!~ndi,~ OPTIONAL Line ~o rnatls~tl~ collt~ectlon I~Oial~g I~tOwOUl i~.'venler J Gaie valve power ope, . DRAWING & CHECK LIST 104A SHELL CLASS 5M SURFACE IN'STALLATIONS NORMAL AIR~GAS" FOR AIR/GAS DRILLING CONFIGURATION A .. o~. ooo BLIND RAM PIPE RAM · / SPIEL[_ WESTERN E&P INC. MIDD[.E GROUND SHOAL FIELD LI' ..5 KSI LINES CIIOSS 3' X 3' X 3' X 3' 5 KSI CI1OSS 3' X 3' X 3' X 3' X 3' 5 KSI 3' 5 KSI GATE VALVE AD,JUSTABLE MANLJAL CI-tOKE 3' 5 KSi I'IEMOTE OPEN:IAI'ED CHOKE 2'9/ 16' 10 KSI ttYORAULIC AIDJUSTASLE P~IESS(,IRE GAGE LINES MilD/GAS SEPAIIATOR 6' I.INE PLATFORM "A" CtlOKE MAttIFOLD vENTED A F CROwN"~"-,, INL E T'-,,,~ Shell Western E&P. Inc. Platform "A" Solids Control/Mud System Desilter 1 6 Cone Sand Derrick Shakers Derrick Shakers Trap To MuC~p umps To Mud~u raps To De~asser To DeCasser Mixers Shell Western E&P Inc. An affiliate of Shell Oil Company P, O. Box 576 Houston, TX 77001 January 19,1995 Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Gentlemen: SUBJECT: SUBMISSION OF FORM 10-401 - APPLICATION FOR PERMIT TO DRILL MIDDLE GROUND SHOAL LATERAL DRAINHOLE WELL NO. A24-01LE Enclosed, in triplicate, is the Application for Permit to Drill a lateral drainhole from Middle Ground Shoal Well No. A24-01 (APl No. 20258-00). The lateral drainhole will be named A24-01LE. Additionally enclosed, in triplicate, is the Application for Sundry Approval to abandon the Middle Ground Shoal - "G" Pool in Well No. A24-01. Operations are scheduled to begin February 20, 1995. If you have any questions or wish to discuss, please call Jeff Wahleithner at (713) 544-3344 or Bert Coxe at (713) 544-2235. Sincerely, G. S. Nady Manager - Asset Administration Westem Asset Enclosures AK401 .DOC- 1 STATE OF ALASKA I ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon--!~-~'' POol. Suspend ~ After casing ~ Repair well Change approved program Operation shutdown Re-enter suspended well . Plugging~ Time extension ~ Stimulate~ Pull tubing __ Variance Perforate __ Other 2. Name of Operator Shell Western l~,P Inc. 3. Address . P.O. Box 576, Houston, TX 77001-0576 5. Type of Well: Development X Exploratory Stratigraphic . Service 4. Location of well at surface PLATF A, LEG 4, COND 28, 1564' FSL & 378' FWL SEC. 11 At top of productive interval '1~,p,J, ~t~V~ $ 9966' RD 5285' FSL & 2095' FWL SEC. 11, T8N, R13W, SM At effective dept~ 10,800' MD, 5699' FSL & 1935' FWL SEC. 11, T8N, R13W, At total depth 10,900' MD, 5743' FSL & 1910' FWL SEC. 11, T8N, R13W, 6. Datum elevation (DF or KB) 116' DF feet 7. Unit or Property name RIDDLE GROUND SHOAL 8. Well number A24-01 9. Permit number 73-38 10. APl number so- 50-733-20258-00 11. Field/Pool RGS "G" POOL 12. Present well condition summary Totaldepth: measured 10,900 feet true vert~ 9482 feet Effective depth: measured true vertical Casing Length Structural Conductor 370' Surface 2010' Intermediate Production 10,888' Liner Perforation depth: measured Plugs (measured) "~ 10,800 feet Junk(measu~d) 1 ,569' 9396 feet · Size ,x~~nte~) ~t~Ioasured depth " · ~, 370' 20 ~0~0 '~010' 13-3/8"~ ~IC SX sx UNDERREARER FISH True vertical depth 370' 1832' 9472' 9663'-1,0,~i34' (x!0 INTERVALS) RECEIVED Tu~ {size/gr,. a~ ~asur~ depth) · A~0[[. EUE e _ Packers a~SSSV (ty~ a~ measur~ depth) GUIBER~0N UNI-PKR~II e 9846', BAKER FV-6 TRSCSSV e 304' 13 ~rati~s ~P sketch 14. Estimated date for commencing operation 2-20-95 16. If proposal was verbally approved Name of approver Date approved 15. Status of well classification as: Oil X Gas Service Suspended 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Skirted q.'[~,..~, . [,),~k~_~. ,F_y~ G. S. NADY Title RGa- ASSET FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness Plug integrity ~ BOP Test ~ Location clearance ~ Mechanical Integrity Test ~ Subsequent form required 10- ADMIN. Date 1/19/95 Approved by order of the Commission Commissioner Date Form 10-403 Rev 06/15/88 SUBMIT IN TRIPLICATE MIDDLE GROUND SHOAL A24-01 ABANDONMENT OF EXISTING HEMLOCK PERFORATIONS Plan Abandon the "G" Pool by setting a cement plug across the existing perforations. Procedure 1. Move to A24-01 (leg 4, conductor 28) and rig up. 2. Kill well. 3. Nipple up 5,000 psi BOP stack and test. 4. Pull tubing and packer completion equipment. 5. GIH with bit and scraper and clean out to TD at approximately 10,569'. 6. Set a cement plug across the Hemlock perforations from TD to 9,500'MD-KB. 7. GIH and clean out cement to 9,966'MD-KB. 8. Use wireline and GR to set a bridge plug at 9,966'MD-KB. WELL PERMIT CHECKLIST oo,. PROGRAM: exp [] der [] redrll ~ serv [] ADMINISTRATION 1. Permit fee attached .................. N 2. Lease number appropriate ............... N 3. Unique well name and number .............. N 4. Well located in a defined pool ............. N 5. Well located proper distance from drlg unit boundary. . N 6. Well located proper distance from other wells ..... N ' 7. Sufficient acreage available in drilling unit ..... N 8. If deviated, is wellbore plat included ........ N 9. Operator only affected party .............. N 10. Operator has appropriate bond in force ......... N 11. Permit can be issued without conservation order .... N 12. Permit can be issued without administrative approval.. N 13. N Can permit be approved before 15-day wait ........ 'f!/ ENGINEERING 14. Conductor string provided ................ Y N 15. Surface casing protects all known USDWs ......... Y N 16. CMT vol adequate to circulate on conductor & surf csg.. Y N 17. CMT vol adequate to tie-in long string to surf csg . . . Y N 18. CMT will cover all known productive horizons ...... ~ N 19. Casing designs adequate for C, T, B & permafrost .... ~ N 20. Adequate tankage or reserve pit ............. Y~/ N 21. If a re-drill, has a 10-403 for abndnmnt been approved..Y N 22. Adequate wellbore separation proposed .......... ~ N 23. If diverter required, is it adequate ........... ~ 24. Drilling fluid program schematic & equip list adequate .~ N 25. BOPEs adequate .................... .~ N 26. BOPE press rating adequate; test to ~6)~_~ psig'~ N 27. 28. 29. Choke manifold complies w/API RP-53 (May 84) ....... ~ N-~.,,'~I- Work will occur without operation shutdown ....... ~ N Is presence of H2S gas probable ............. Y ~ , , , GEOLOGY 30. Permit can be issued w/o hydrogen sulfide measures .... Y N/~ 31. Data presented on potential overpressure zones ..... Y 32. Seismic analysis 9f shallow gas zones .......... 33. Seabed condition survey (if off-shore) ........ / N 34. Contact name/phone for weekly progress reports .... /. Y N [exploratory only] GEOLOGY: COMMISSION: ENGINEERING: JDH c~ RAD~ Comments/Instructions: HOW/jo - A:~FORM,..,~cheklist rev 03/94 o , Z o