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Home My WebLink About167-026MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE:Thursday, May 11, 2023 SUBJECT:Mechanical Integrity Tests TO: FROM:Sully Sullivan P.I. Supervisor Petroleum Inspector NON-CONFIDENTIAL Hilcorp Alaska, LLC 02 BEAVER CK UNIT 02 Jim Regg InspectorSrc: Reviewed By: P.I. Suprv Comm ________ JBR 05/11/2023 02 50-133-20021-00-00 167-026-0 W SPT 4923 1670260 1500 1330 1325 1316 1307 5 5 5 5 4YRTST P Sully Sullivan 4/4/2023 MIT IA , operator chose to pt to 1900 (1841) psi 30 MinPretestInitial15 Min Well Name Type Test Notes: Interval P/F Well Permit Number: Type Inj TVD PTD Test psi API Well Number Inspector Name:BEAVER CK UNIT 02 Inspection Date: Tubing OA Packer Depth 989 1841 1835 1834IA 45 Min 60 Min Rel Insp Num: Insp Num:mitSTS230407153258 BBL Pumped:1 BBL Returned:1 Thursday, May 11, 2023 Page 1 of 1            MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Tuesday, April 9, 2019 TO: Jim Regg P.I. Supervisor w5 I Z'II SUBJECT: Mechanical Integrity Tests HILCORP ALASKA LLC 02 FROM: Austin McLeod BEAVER CK UNIT 02 Petroleum Inspector Src: Inspector Reviewed By: P.I. Sup" RT -7 NON -CONFIDENTIAL Comm I Well Name BEAVER CK UNIT 02 Insp Num: mitSAM190405233525 Rel Insp Num: API Well Number 50-133-20021-00-00 Inspector Name: Austin McLeod Permit Number: 167-026-0 Inspection Date: 4/4/2019 - Packer Depth Well oz Type Inj N ITVD 4923 PTD 1670260 Type Test sPT ;T Ise pst 1500 BBL Pumped: 1.1 BBL Returned: 13 Interval 4YRTST �P/F 1' —_ - Notes: MIT -IA. Not online at test nine. Batch injecting. Pretest Initial 15 Min 30 Min 45 Min 60 Min ubing 408 -lox 40s 408 ' IA - 759 1799 1795 - 1794 OA a 3 Tuesday, April 9, 2019 Page 1 of I • • AOGCC Docket 10 -12 MIT Test Anniversary Dates Marathon Oil Company . ; o y it !I nil Request Dated May 26, 2010 Background Marathon requested changing the anniversary dates of eight Kenai Peninsula injection wells to allow the mechanical integrity test (MIT) required by regulation/order to be performed during summer months. Marathon proposed the wells be adjusted to show a September 1 anniversary date. Action Marathon's email request dated May 26, 2010 followed several telephone discussions between Kevin Skiba (Marathon; 907 - 283 -1371) and Jim Regg (AOGCC; 907 - 793 - 1236). Subsequent to the email request, telephone discussions were held on June 1, 2010, February 7, 2011 and February 8, 2011. Mr. Skiba was told that the following during discussions: - MIT due date can be changed by simply scheduling the test during the summer months; - Tests must be completed in advance of the next due date; - Make sure to give AOGCC Inspectors the required advance notice to allow for opportunity to witness; AOGCC witness is required to adjust the anniversary date; - Industry Guidance Bulletin 10 -002 provides details about testing injectors for mechanical integrity. Marathon was told the proposed September 1 anniversary date would not work for all wells since some MITs would be performed later than the currently required anniversary date. Resulting from the guidance provided to Marathon, the anniversary date for each of the eight injection wells has been changed based on successful, witnessed MITs as shown below: Well PTD MIT Completed Next MIT Due •Beaver Creek Unit 2 1670260 5/4/2011 5/4/2015 Kenai Beluga Unit 23x -6 1841090 5/25/2011 5/25/2015 Kenai Unit 11 -17 1811760 5/3/2011 5/3/2013 Kenai Unit 12 -17 2080890 5/3/2011 5/3/2013 Kenai Unit 24 -07RD 2050990 5/3/2011 5/3/2015 Kenai Unit 31 -7X 2001480 5/25/2011 5/25/2015 Kenai Unit WD -1 1811070 5/3/2011 5/3/2015 Sterling Unit 43 -09 1630110 5/4/2011 5/4/2015 With MITs completed on these wells during May 2011, Docket 10 -12 can be closed. B .2� James B. Regg + 1 October 6, 2011 7 _ ____ • • • Colombie, Jody J (DOA) From: Regg, James B (DOA) Sent: Wednesday, May 26, 2010 11:25 AM To: Colombie, Jody J (DOA) Subject: FW: MIT tests anniversary date setup Jim Regg AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 907 - 793 -1236 From: Skiba, Kevin J. [mailto:kskiba ©marathonoil.com] Sent: Wednesday, May 26, 2010 11:10 AM To: Regg, James B (DOA) Subject: MIT tests anniversary date setup Jim, Below is a list of Marathon Alaska's injection well MIT dates. Well Last test Frequency Next test BC -2 1/15/08 4 -year 1/15/12 KBU 23x -6 6/4/07 4 -year 6/4/11 KU 11 -17 5/12/10 1 -year 5/12/11 KU12 -17 8/27/09 2 -year 8/27/11 KU 24 -7RD 2/12/10 2 -year 2/12/12 KU 31 -7x 8/8/07 4 -year 8/8/11 SU 43 -9 5/13/09 2 -year 5/13/11 WD -1 5/12/10 4 -years 5/12/14 As per our telephone conversation, we would like to set up an anniversary date for the MIT tests on these wells. As stated, the anniversary date would allow us to complete the MIT tests in the summer months without having the forward movement affect on the test dates. With that said, we are interested in a September 1 date as the anniversary date. Please let me know if you need any additional information concerning this request. Thanks again, Kevin Skiba Regulatory Compliance Representative Marathon Alaska Production LLC i Office 907 283 -1371 b ( ) • Cell (907) 394 -1880 Fax (907) 283 -1350 2 • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Friday, May 27, 2011 TO: Jim Regg P.I. Supervisor ' C Sizi/ll SUBJECT: Mechanical Integrity Tests MARATHON OIL CO 02 FROM: John Crisp BEAVER CK UNIT 02 Petroleum Inspector Src: Inspector Reviewed BY: P.I. SuprvJ.gg— NON- CONFIDENTIAL Comm Well Name: BEAVER CK UNIT 02 API Well Number: 50- 133 - 20021 -00 -00 Inspector Name: John Crisp Insp Num: mitJCr1 1 0505 142443 Permit Number: 167 -026 -0 Inspection Date: 5/4/2011 Rd Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well i T 02 Type Inj. W ' TVD 4923 IA I 120 I 1630 - 1610 1600 ' P. T.DI 1670260 ' TypeTest SPT Test psi 1500 n OA o 0 0 0 Interval 4YRTST P/F P Tubing 2200 2240 2350 2360 Notes: 88 gal. 80/20 methanol pumped for test. Worked with production to start injection approximately 15 minutes prior to IA MIT. Talked with my Supervisor Jim Regg about the low AOGCC pressure requirments for this MIT compared to the relatively high tubing injection pressure. Jim will make pass /fail determination. Jim Regg determined test was a pass. Wellbore schematic along with injection graph will be attached to report. �'j JUN ) I Z011 Friday, May 27, 2011 Page 1 of 1 l ir 1 67 - ° BC -2 • WTM OM Conductor Pad 2 (Injection Weli) « 7 4 :: ! ; �� 8 .41,1,44/ ` 4 / , 20" H-40 94 ppf 590' FNL, 1,979' FEL Tom ` S off) Sec. 3, T6N R10W S.M. MD o' Bottom zao v .;� 1 ,r " 't e ✓`!•yr 3,' r r TVD 0' 280' 26 hole Cmt w/ 525 sks of Class G o ' t e. 20 15 hrs 7113/1967 Surface Casing 9 d - 1%t'a ,-- I & 72 E e ] 61s8 � 12/ 13 -3/8" j T� & Bottom Y 1 �� , a� - MD N -80 0' J -55 68 2,211' ppf E TVD 0' 2,211' E 17 -1/2" hole Cm-t w/ 2,000 sks of Class G ` i f r t Intermediate ' 9 -518" N & - 40 & 47 ppf `' Top Bottom MD 0' S 95 _ 8,835' e� k TVD 0' 8,835' -80 12 -1/4" hole plug Cmt floats w/ 1,370 held sks of Class G ._ ,tyt. 9$41, , -� i. , t Bumped i Production Liner Production Tubing 7" M N -80 & P -110 29 & 339' 2 ppf 3 -1/2" N -80 9.2_P...!, p D s s2 Bottom Otis XA circ sleeve 4, f% s,2sa' I ' 1 5'439' Baker FH hyd packer 4,923' 8 -1/2" hole Cmt w/ 650 sks Baker W L entry guide 4,961' l Liner Packer @: ii j �� Cement top @ 13,800' I Top of Cement Liner 5" N -80 18 ppf FJ Hydrill @ 3,508' "` Tom Bottom CBL Aug. 1967 l ----=t-7-.___ ,' ,697" 1 TVD 15,415' 15,697 f - mow. 6" MD hole Cm w 41 sacks Illtlir el k 1i Tag @ 5,167' MD �; Perforations: MD /TVD Date 2.00" DD Bailer on (2/3/10) B -1: 5,007- 5,028' I Sterling Sterling B -1 5,032'- 5,052' =a ill Sterling B -2: : 5,124'- 5,140' 10/27/1988 Sterling B - 3: 5,155' - 5,175' 11/24/1967 n fig) i Sterling B -3: 5,155' - 5,197' 10/27/1988 a icC Ste B - 5,155'- 5,' 1212411967 » ' ' M " r ' a Isolated Per rling for ations: 13 23'tota1iertgth 5"19.7 Sterling B -3a: 5,229' - 5 ,244' 12/24/1967 Sterling B-4: 5,324'- 5,344' 12/24/1967 Hem 14,942'- 14,' 67 Hem ock: 4,942' - 14,962' 12/6/1967 Cement Cap @ 5,197' " 1 Hemlock: 14,964'- 14,974 10/24 Cement Retainer @ 5,221' Hemlock: 14,990'- 15,020' 10/25/1967 Hemlock: 14,994'- 15,009' 1216/1967 5,290' Hemlock: 15, - 15,058' 10/2511967 ck 15,037'- 15 15 ,057 00 ' Ire Hemlock: : 1 5,0 63 '- 1 5 220 , 0 73' - Hemlo 5,644' Hemlock: ', 1' 10/26/1967 12/6/1967 x 15,080 ' Hemlock 15,085' - 1 5,100' 1217/1967 10/26/1967 8,345 Hemlock: 15 15 12/611967 Hemlock: 15,158'- 15,248' 1 012 211 9 6 a - 7 a Hemlock: 15 15 12/711967 14,265' Hemlock: 15,285' - 15,345' 10/21/1967 /1 - K Hemlock: ,290'- 15,310' 121797 `-4-- -- 15,410' Hemlock: 15,356'- 15,386' 10120/196 -Fill @ 5,132' SLM (11/11/01) Hemlock: 15,452'- 15,537' 11/19/1967 -CTU Clean out to 5,197' (1/30/09) Hemlock: 15 15 ,560' - 15,585' 11/19/1967 3,000 gal, 15% HCL / 3 %, HF acid job 11 L TD PBTD 15,697' MD 5,197' MD 15,697' TVD 5,197' TVD Well Name & Number: Beaver Creek #2, Class II Disposal Well Lease: Beaver Creek, Pad -2 County or Parish: Kenai Penisula Borough State: Alaska Country:/ USA Angle @ KOP and Depth: Vertical Hole Angle /Perfs: 0° Date Completed: 10/20/1967 RKB: 15' I Ground level:/ 140' Revised by Kevin Skiba Last Revision Date: 2/15/2010 . p L-- c._ • rt12A'707 1 s;50,t5 159 psi � � � • _ (4/1/2011 7:08:15 AM) 138 psi -20 psi (62 days, 23:18:00) 1000 500 5000 l I 1 o ■ a II ■ 1 • • ■ a II ■ % ■ • • ■ • • B e • ® ®sr• d • ■ • ■■ • ® ■ la fa • i t • • e a al ■ . roe, . i , , , 1 ) ,,,,, II\41 \ i'll \ c ' ' 1° 1 1 ( \1-4111 \ ' I 1 i ' . . . 1 o / 0 - A 1 ' II : 1 ) : I h I I i I 1/14/2011 2/1/2011 2/19/2011 3/9/2011 3/27(2011 4/14/2011 6:59:15 PM 6:47:15 PM 6:35:15 PM 6:23:15 PM 7:11:15 PM 6:59:15 PM I Tag Name ( DeSeriptiOn l Server odor Unfits I Minimum 1 Merarnm I'IOAddt'ess ! line offset I a MEIMBIONINEM BC2 Wel 2 inner Casing Pressure KGFR5969 ,. psi 0 500 11KGFR5 %9unSQLMD... 0:00:00.... ® W AK_BC2_Wel2.C5G Ot.er_PT BC2 Wel 2 Outer Casing Pressure KGFR5%9 psi 0 5000 11KGFR5969Un5QL MD,.. 0:00:00.... ® (1: AK 8C2_We92.Inj FR BC2 Well 2 Injection Flowrate from Pad IA KGFRS969 BPD 0 1000 11KGFR5 %911n5QL MD... 0:00:00.... ® AK BC2 We82.Inj_TVoi BC2 Wei 2 Today's Total Injection from Pa.,. KGFR5969 BPD 0 500 11KGFR596911n5QL MD... 0:00:00.... El IL AKBC2_We02.TBG PT 0C2 Wel 2 Tubing Pressure KGFRS %9 psi 0 5000 11KGFR5969Un5QL MD... 0:00:00.... ❑ W AK BC2 _ WeP2.TBG TT BC2 Wel 2 1td*s Temperature KGFRS969 °F 0 100 11 KGFR596911n5QL MD... 0:00:00.... • MIT frequency 9 Maunder, Thomas E (DOA) From: Regg, James B (DOA) Sent: Tuesday, February 16, 2010 1:29 PM To: Miranda, Kyle Cc: Maunder, Thomas E (DOA); DOA AOGCC Prudhoe Bay Subject: RE: MIT frequency Page 1 of 2 Reviewed your list against AOGCC well records and injection orders; edits in red below. KU 24-07RD test cycle is 2 years; only info in our files indicates well is a slurry injector. Looks like only 2 remaining test due this year: _ - KU 11-17, due on or before 5/13/2010 - KU WD -1, due on or before 5/18/2010 Jim Regg AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 907-793-1236 From: Miranda, Kyle [mailto:kmiranda@marathonoil.com] Sent: Monday, February 15, 2010 2:52 PM To: Regg, James B (DOA) Subject: MIT frequency Jim, I wanted to verify that we were both on the same page regarding our MIT frequency requirements. Below is what I believe to be correct, with our most up to date well files. When you get the chance, could you please verify? In the meantime however, there was a discrepancy on KU 24-7rd whether it was a 2 or a 4 year. Searching your well file database I still believe it to be every 4 years, but wanted to confirm this as your inspector indicated he thought it was 2 years. We will send out our completed MIT test form for our recent test on KU 24-7rd when we have confirmed. Thanks. ---------------------------------------------- ---------------------------------------------- Well Freq PTD KU 24-7rd (4 year) 205-099 2yr, next due 2/12/2012 KU 11-17 (1 year) 181-176 next due 5/13/2010 WD 1 (4 year) 181-107 next due 5/18/2010 SU 43-9 (2 year) 163-011 next due 5/13/2011 KBU 23x-6 (4 year) 184-109 next due 6/20/2011 KU 31-7x (4 year) 200-148 next due 8/8/2011 - 7 2 ear 208-089 next due 8/27/2011 BC 2 (4 year) 167-026 next due 1/15/2012 9/28/2010 • • Marathon Oil Company Alaska Asset Team M Marathon P.O. Box 1949 Kenai, AK 99611 MARATHON Oil Company Telephone 907/283-1371 Fax 907/283-1350 April 3, 2009 Mr. Tom Maunder Alaska Oil & Gas Conservation Commission 333 W 7t" Ave Anchorage, Alaska 99501 ~ ~~ Reference: 10-404 Report of Sundry Well Operations ~~~ Field: Beaver Creek Field Well: Beaver Creek #2 ~ k~~~,~~~~r~~ ~,~~~~~~ ~ ~~ ~~~:" Dear Mr. Maunder: Attached for your records is the Report of Sundry Well Operations, 10-404, for BC-2 well. This sundry is being submitted to close out the waiver granted under sundry approval #308-093. A Mechanical Integrity Test was performed on this well confirming that there is no communication between the casing and tubing string. Please contact me at (907) 283 -1371 if you have any questions or need additional information. Sincerely, {~U~~ Kevin J. Skiba Engineering Technician Enclosures: 10-404 Report of Sundry Well Operations cc: Houston Well File Mechanical Integrity Test Kenai Well File KJS JKM STATE OF ALASKA ALA OIL AND GAS CONSERVATION COMM~ ION REPORT OF SUNDRY WELL OPERATIONS -~~ bl ~~ ~ 1. Operations Abandon Repair Well Plug Perforations Stimulate Other P rf d e orme v~ : Alter Casing ^ Pull Tubing ^ Pertorate New Pool ^ Waiver^~ Time Extension ^ ~.hsSc Change Approved Program ^ Operat. Shutdown ^ Perforate ^ Re-enter Suspended Well ^ 2. Operator Marathon Oil Company N 4. Well Class Before Work: 5. Permit to Drill Number: ame: Development ~• Exploratory^ 167-026 - 3. Address: PO Box 1949 Stratigraphic ^ Service ^ 6. API Number: Kenai Alaska, 99611-1949 50-133-20021-00-00 ' 7. KB Elevation (ft): 9. Well Name and Number: 155' Beaver Creek # 2 - 8. Property Designation: 10. Field/Pool(s): FEDA 028118 Beaver Creek Field /Sterling Pool 11. Present Well Condition Summary: Total Depth measured 15,697' - feet Plugs (measured) 5,197' true vertical 15,69T ~ feet Junk (measured) Nq Effective Depth measured 5,197' feet true vertical 5,197' feet Casing Length Size MD TVD Burst Collapse Structural 265' 20" 280' 280' NA NA Conductor Surface 2,196' 13-3/8" 2,211' 2,211' 3,450 psi 1,950 psi Intermediate 8,820' 9-5/8" 8,835' 8,835' 6,330 psi 3,810 psi Production 10,171' 7" 15,439' 15,439' 8,160 psi 7,020 psi Liner 258' S" 15,697' 15,697' 10,140 psi 10,490 psi Perforation depth: Measured depth: 5,007' - 5,220' True Vertical depth: 5,007' - 5,220' Tubing: (size, grade, and measured depth) 3-1/2" N - 80 4,961' Packers and SSSV (type and measured depth) Baker FH Packer 4,961' 12. Stimulation or cement squeeze summary: Intervals treated (measured): The pressures in the tubing and casing have been monitoured for the past year to determine if there is communication between them. An MIT was performed on 1/15/08 confirming that no communication Treatment descriptions including volumes used and final pressure: exists. 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: NA - - - - Subsequent to operation: NA - - - - 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run Exploratory ^ Development ^ Service Q Daily Report of Well Operations 16. Well Status after work: Oil ^ Gas ^ WAG ^ GINJ ^ WINJ ^ WDSPL ~° 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 308-093 Contact Kevin Skiba (907) 283-1371 Printed Name Kyle J. Miranda ~ Title Production Engineer Signature Phone (907) 283-1370 Date April 3, 2009 Form 10-404 Revised 04/2006 ~ ~ •~ ~'~ ~ ~ ~ ~; «) ~ ~~~~ ~~~ ubmit Original On ~/ ~i0~ (~~! C~ J Email to:jim.regg@alaska.gov; tom.maunder@alaska.gov;bob.fleckenstein@alaska.gov;doa.aogcc.prudhoe.bay@alaska.gov OPERATOR: FIELD /UNIT /PAD: DATE: OPERATOR REP: AOGCC REP: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Marathon Oil Company Beaver Creek Unit /Pad 2 01/15/08 Ray Schemanski Not Witnessed • Packer Depth Pretest Initial 15 Min. 30 Min. Well BC-2 Type Inj. W TVD 4,923' Tubing 237 1,718 1,048 736 Interval V P.T.D. 167-026 Type test P Test psi 1,794 Casing 500 1,794 1,782 1,778 P/F P Notes: Test performed because of unexplained pressure OA 0 0 0 0 increase on inner casing 12117/07. The tubing See trend in well file for additional pressure was not stable during test due to the information. effects associated with a pump injection cycle. Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA TYPE INJ Codes D =Drilling Waste G=Gas I =Industrial Wastewater N =Not Injecting W =Water TYPE TEST Codes M =Annulus Monitoring P =Standard Pressure Test R = Internal Radioactive Tracer Survey A =Temperature Anomaly Survey D =Differential Temperature Test INTERVAL Codes I =Initial Test 4 =Four Year Cycle V =Required by Variance T =Test during Workover O =Other (describe in notes) MIT Report Form BFL 11/27/07 BC-2 MIT Test 011508.x1s ~~ 5~ From: Regg, James B (DOA) [mailto:jim.regg@alaska.gov] ~~, ~9 ~~bt~~ Sent: Wednesday, March 04, 2009 3:27 PM ~ 1 To: Miranda, Kyle Subject: RE: BC 2 -Monthly Injection Report PTD#167-026 -February 2009 Well integrity waiver requires a 10-404 (see attached sundry 308-093 approval) to cancel. Please also provide a cover letter and attach your email below -info appears to be a good basis for your request. Jim Regg AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 907-793-1236 From: Miranda, Kyle [mailto:kmiranda@marathonoil.com] Sent: Wednesday, March 04, 2009 1:50 PM .~7 ~~ ~,I ~ ~0~ To: Regg, James B (DOA) 1`~ `~ Subject: FW: BC 2 -Monthly Injection Report PTD#167-026 -February 2009 Mr. Regg: I believe these reports were intended to be sent to you to verify no communication existed to the outer annulus of the BC 2 well, after an incident in December 2007 suggesting there might be communication. An MIT was performed on this well on 1/15/08 and the test passed, there was no communication between the casings and tubing. Since then, these reports have shown no abnormalities in the well or unexplained casing pressure increases. Additionally, as noted below, a coiled tubing cleanout and acid job were performed in January 2009 to reduce wellhead pressure. This job was successful (see below) in that it reduced wellhead pressure during injection and post injection, as well as expedited fall-off time. During the job, and in the month afterward, we have still seen no evidence of communication. Per the above facts, and in an effort to save both your time and Marathon's time, may we discontinue forwarding the monthly monitoring reports? Marathon fully understands that any unexplained pressure increase or communication in the future will be immediately reported to the __ AOGCC, and reports would be provided as requested at that time. Please let me know if you agree, ~~ - Thank you, Kyle Miranda Production Engineer I Marathon Oil Company-Alaska Asset Team 907-283-1370 (office) 907-394-8271 (cell) ~~ `'n°`35W-~ ~~rhti «-. r !~ Wp~L Q_ ~ La.- J (3c-z ,~ P~ r6~ ~~ (~~/ 4~~b~©g From: Miranda, Kyle Sent: Wednesday, March 04, 2009 9:23 AM To: 'jim.regg@alaska.gov' Cc: Ibele, Lyndon; Walsh, Ken; Dammeyer, Michael D.; Miranda, Kyle Subject: BC 2 -Monthly Injection Report PTD#167-026 -February 2009 BC 2 -Injection Summary PTD167-026 -February 2009 -Marathon Oil Company Enclosed is the Beaver Creek 2 Injection Summary PTD167-026 for February 2009, submitted monthly via email. Quick Summary: Everything remains within the guidelines, that is: 1) The Inner Annulus Pressure has remained below 1000 psig. 2) No communication to the Outer Annulus has been realized. 3) No OA or IA pressure bleeds were performed. Please note: - From 1/21/09 - 1/31/09 a cleanout of the wellbore and acid stimulation was performed to reduce overall injection pressure -Analysis indicates the job was successful in reducing injection pressure: - In the month of February, maximum averages for wellhead pressure during injection was 2000 psi. In January (before cleanout job), the maximum average was -2500 psi. - In the month of February, post injection bleed off would reach a low average of 0 to 750 psi. In January (before cleanout job), the post injection bleed off would reach a low average of 1750 psi. Any questions or concerns, please do not hesitate to call or email. Kyle Miranda Production Engineer I Marathon Oil Company-Alaska Asset Team 907-283-1370 (office) 907-394-8271 (cell) Items included in the BC 2 reoort: 1. Flowrate (BPD) 2. Inner Annulus Pressure (psig) (must stay below 1000 psig) 3. Outer Annulus Pressure (psig) (must notify the AOGCC if any communication is realized) 4. Tubing Pressure (psig) 5. Volume Injected (BPD) 6. All OA and IA Pressure Bleeds «BC2 Feb 2009 Injection Summary PTD167026.ZIP» BC 2 -Monthly Injection Rep~PTD#167-026 -March 2009 Regg, James B (DOA) From: Miranda, Kyle [kmiranda@marathonoil.com] Sent: Wednesday, April 01, 2009 9:52 AM To: Regg, James B (DOA) Cc: Ibele, Lyndon; Walsh, Ken; Dammeyer, Michael D.; Miranda, Kyle Subject: BC 2 -Monthly Injection Report PTb#167-026 -March 2009 Attachments: BC2 Mar 2009 Injection Summary PTD167026.ZIP BC 2 -Injection Summary PTD167-026 -March 2009 -Marathon Oil Company Page 1 of 1 Enclosed is the Beaver Creek 2 injection Summary PTD167-026 for March 2009, submitted monthly via email. Quick Summary: Everything remains within the guidelines, that is: 1) The Inner Annulus Pressure has remained below 1000 psig. "~ 2) No communication to the Outer Annulus has been realized. ~ 3) No OA or IA pressure bleeds were performed. ~ Any questions or concerns, please do not hesitate to tali or email. Kyle Miranda Production Engineer I Marathon Oil Company-Alaska Asset Team t~='~~rt ~. ,t, '~ ~t C 907-283-1370 (office) ~'' ~~~ ~ ~~~ 907-394-8271 (cell) Items included in the BC 2 report: 1. Flowrate (BPD) 2. Inner Annulus Pressure (psig) (must stay below 1000 psig) 3. Outer Annulus Pressure (psig) (must notify the AOGCC if any communication is realized) 4. Tubing Pressure (psig) 5. Volume Injected (BPD) 6. All OA and IA Pressure Bleeds «BC2 Mar 2009 Injection Summary PTD167026.ZIP» 4/1 /2009 (Bisd) aanssaad • °o ~°n °o ~°n °o ion oon °0 0 0 0 O I~ LC) N O f~ ~ N O Ln O ~ M N N N N ~ ~ ~ ~ I~ to N O .~ ~. ~ a~ m~ a~ ~~ o.E >~ ~~ a~ ~ U~ .°~ O cl~ ~T ~I ca ~~ E E N C O m .~ _ .~ ~ o~ c o Q o N ~ L ~ ea ~ ~ N • • U m 0 a m~ `. a~ 3• 0 ^ • 4/1 /2009 3/31 /2009 3/30/2009 3/29/2009 3/28/2009 3/27/2009 3/26/2009 3/25/2009 3/24/2009 3/23/2009 3/22/2009 3/21 /2009 3/20/2009 3/19/2009 3/18/2009 3/17/2009 ~ 3/16/2009 F- 3/15/2009 3/14/2009 3/13/2009 3/12/2009 3/11 /2009 3/10/2009 3/9/2009 3/8/2009 3/7/2009 3/6/2009 3/5/2009 3/4/2009 3/3/2009 3/2/2009 3/1 /2009 0 0 0 0 0 0 0 0 0 0 0 0 0 '~ N O 0p CO ~ N O 00 O ~ N d' M N O O O ~ O ~ M N ~ ~ ~ ~ r O c c Q C c 0 a c F- • ~ ~~ .~ ~ ~~ ^ ~_ • : ~ '~ : ••..~ . ~ ~ ~• ~ .r... ~ • ^ • ~.~~ ~ : • • . i. • ~ ..M ^ ~ ~. I ~ wy ~~ ~ ~ ~ .'~'' ~• •~ ~• • • ^ ~' N ~ M~ • 1 s• •• Z ~• • ~~ ~ • • • • '~ ~ i~ i • ^ ~' ~~ ~ •~•• • «r • • • • ~ ~ ~ ~ :~ ^ ~ . ^ a •rr.. ~ ~ ~ : ... ~ ^ ; c ••.• • • ^ a~ ~ • • • ~ t ~ ~ ~ .r. ~ ~ ~ ~ • O rr~ f ri N ~~ ~• ~r • • • ~ ^ r~1 S~• • M~~ ~ ~~ •• • • ~^r ~ (ddb) auan~on pue a;eannol~ • ,~r~ ~~ ZL~~~ Inner Annulus Pressure Bleeds Date Time Pressure (before) Pressure (after) None None None None Outer Annulus Pressure Bleeds Date Time Pressure (before) Pressure (after) None None None None BC 2 -Monthly Injection Report PTD#167-026 -February 2009 Regg, James B (DOA) From: Miranda, Kyle [kmiranda@marathonoil.com] f Sent: Wednesday, March 04, 2009 9:23 AM ~" N ~~ To: Regg, James B (DOA) `"~ Cc: Ibele, Lyndon; Walsh, Ken; Dammeyer, Michael D.; Miranda, Kyle Subject: BC 2 -Monthly Injection Report PTD#167-026 -February 2009 Attachments: BC2 Feb 2009 Injection Summary PTD167026.ZIP BC 2 -Injection Summary PTD167-026 -February 2009 -Marathon Oil Company Page 1 of 2 Enclosed is the Beaver Creek 2 Injection Summary PTD167-026 for February 2009, submitted monthly via email. Quick Summary: Everything remains within the guidelines, that is: ~ i ~~~ ~~ ~~ tutu 1) The Inner Annulus Pressure has remained below 1000 psig. L,~~'~`~'~'` ' " 2) No communication to the Outer Annulus has been realized. 3) No OA or IA pressure bleeds were performed. Please note: - From 1021f09 - 1/31109 a cleanout of the wellbore and acid stimulation was performed to reduce overall injection pressure -Analysis indicates the job was successful in reducing injection pressure: - In the month of February, maximum averages for wellhead pressure during injection was -2000 psi. In January {before cleanout job), the maximum average was 2500 psi. - In the month of February, post injection bleed off would reach a low average of 0 to 750 psi. In January {before cleanout job), the post injection bleed off would reach a low average of 1750 psi. Any questions or concerns, please do not hesitate to call or email. Kyle Miranda Production Engineer 1 Marathon Oil Company-Alaska Asset Team 907-283-1370 (office; 907-394-8271 (cell) Items included in the BC 2 1. Flowrate (BPD) 2. Inner Annulus Pressure (psig) (must stay below 1000 psig) 3. Outer Annulus Pressure (psig) (must notify the AOGCC if any communication is realized) 4. Tubing Pressure (psig) 5. Volume Injected (BPD) 6. All OA and IA Pressure Bleeds 3/4/2009 BC 2 -Monthly Injection Report PTD#167-026 -February 2009 Page 2 of 2 • • «BC2 Feb 2009 Injection Summary PTD167026.ZIP>> 3/4/2009 (6isd) a~nssa~d °o .°n °o °n °o ~°n o ~°n o 0 0 0 O f~ In N O t~ lI') N O ~ O ~ M N N N N ~ ~ ~ ~ I~ ~ N O • -~-- i -- 3/1 /2009 _ _ •r ~' 2/28/2009 rn I ; .! • . ~• ! ~ it ^ ~ 2/27/2009 o ~ ~ ~ .r ~ • :.~ ~ • ~ ~~~ • 2/26/2009 m ~ ; ... ~', • • .,. • ~ ~ 2/25/2009 a F 2/24/2009 > ~ ~ ••'!•"" ~ 2/23/2009 • •••• T 2/22/2009 v~ ! ~•~•i•• • •~•• • • - ~ ! • • ~ .• : ~.:" ~ ~ 2/21 /2009 ^ T ~"" ~ ' t• ~ I ~ ~ 2/20/2009 •~. ~, i I ~ r,• 1 `~~~ ~ o • • : • • ~ 2/19/2009 E , 'l~~~• ~j =', ~ , ~ ' • • • • •', `~ 2/18/2009 _ ~ ifl.~'~~~•••~ • I ~ • , ~ i••~•*•• ;,~••.• •!, • ; • •!, • •~ 2/17/2009 .-. 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': • • iI •• r • • • ~ • ~ • • ~-. ~ 2/8/2009 0 ~ any ~• i~ y~~i • ~ • •i•• 2/7/2009 pip .Q ~ ~ p • I•: ~ 4 • • • • ~i • •i ~• • ~r/~ 2/6/2009 m •~'~ ~. ;, ~•• ~ • • • : ~ • 2/5/2009 ~ ~ ~ ~ • •,~• ti ~ ~ •• • 2/4/2009 i ^ • } ~ ~ •~ ~j~^ ~ • ~ • ~ , ` ' ;~ 2/3/2009 •; • • ~~ • ~ 2/2/2009 • • • • ~ ~ i ~- 2/1 /2009 0 0 0 0 0 0 0 0 0 0 0 0 0 ~ N O 00 Cfl ~' N O 00 (O ~ N ~ M N O O ~ ti O '7 M N ~ r ~- r r (ddb) awn~on pue a;e~nno~~ Inner Annulus Pressure Bleeds Date Time Pressure (before) Pressure (after) None None None None Outer Annulus Pressure Bleeds Date Time Pressure before Pressure after None None None None Page 1 of 1 • Maunder, Thomas E (DOA) From: Sulley, Michael [msulley1 @marathonoil.com] Sent: Wednesday, February 18, 2009 7:40 AM To: Maunder, Thomas E (DOA) Subject: FW: BC-02 (167-026) Tom, BC-2 was my job. After talking to you yesterday, I reviewed my daily reports. You are right. I under tested the lubricator a couple of days. I appreciate you bringing this to my attention. I will be more vigilant in the future. Respectfully, Mike Sulley From: Skiba, Kevin 7. Sent: Tuesday, February 17, 2009 3:53 PM To: Sulley, Michael Subject: FW: BC-02 (167-026) Kevin Slaba Production Technician Marathon Oil Company Office (907) 283-1371 Cell (907) 394-1332 Fax (907)283-1350 From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Tuesday, February 17, 2009 2:48 PM To: Skiba, Kevin J. Subject: BC-02 (167-026) Kevin, Please forward this note to the engineer. I am reviewing the report submitted for the recent CT cleanout. It appears that a variety of test pressures were employed to shell test the CT BOP at the start of daily operations. Some of the shell test pressures were less than the wellhead pressure reported shortly thereafter. What is Marathon's normal practice for shell test pressure testing CT BOPS? Thanks in advance. Tom Maunder, PE AOGCC 2/18/2009 M Marathon MARATHON Oil Company February 11, 2009 ~~ . ~~Q "~ ~~ ~o • Marathon Oil Company Alaska Asset Team P.O. Box 1949 Kenai, AK 99611 Telephone 907/283-1371 Fax 907/283-1350 Mr. Tom Maunder ~~ Alaska Oil & Gas Conservation Commission , ~ 333 W 7th Ave Anchorage, Alaska 99501 ,~~~ Reference: 10-404 Report of Sundry Well Operations Field: Beaver Creek Field Well: Beaver Creek #2 Dear Mr. Maunder: Attached for your records is the Report of Sundry Well Operations 10-404 for BC-2 well. This sundry covers the Coil Tubing Clean Out and Mud Acid stimulation work performed under Sundry #308-457. A blend of HCL, HF Mud Acid & Ammonium Chloride was pumped into the Sterling formation in stages. This resulted in a Wellhead pressure reduction of approximately 784 psi during injection. Please contact me at (907) 283 -1371 if you have any questions or need additional information. Sincerely, - -~~~lJ~ Kevin J. Skiba Engineering Technician Enclosures: 10-404 Report of Sundry Well Operations cc: Houston Well File Operations Summary Kenai Well File Current Well Schematic JKM KJS STATE OF ALASKA ALA OIL AND GAS CONSERVATION C O REPORT OF SUNDRY WELL OPEE~4~1~ ~-~~ 09 1. Operations Abandon Repair Well Plug Perforation $ i1S. 011`tCi11S r ' Coil Tubing Clean Performed: Alter Casing ^ Pull Tubing^ Perforate New Pool ^ W~jfQ~9~~ Time Extension^ Out and Mud - ChangeApproved Program ^ Operat. Shutdown^ Perforate ^ Re-enter Suspended Well^ Acid Treatment 2. Operator Marathon Oil Company Name 4. Well Class Before Work: 5. Permit to Drill Number: : Development Exploratory^ 167-026 3. Address: PO BOX 1949 Stratigraphic ^ Service[ 6. API Number: Kenai Alaska, 99611-1949 50-133-20021-00-00 7. KB Elevation (ft): 9. Well Name and Number: 155' KB (15' AGL) Beaver Creek #2 8. Property Designation: 10. Field/Pool(s): FED A-028118 " Beaver Creek Field /Sterling Formation 11. Present Well Condition Summary: Total Depth measured 15,697' - feet Plugs (measured) 5,197' true vertical 15,697 . feet Junk (measured) NA Effective Depth measured 5,197' feet true vertical 5,197' feet Casing Length Size MD TVD Burst Collapse Structural Conductor 265' 20" 280' 280' NA NA Surface 2,196' 13-3/8" 2,211' 2,211' 3,450 psi 1,950 psi Intermediate 8,820' 9-5/8" 8,835' 8,835' 6,330 psi 3,610 psi Production 10,171' 7" 15,439' 15,439' 8,160 psi 7,020 psi Liner 2g2' S" 15,697' 15,697' 10,140 psi 10,490 psi Perforation depth: Measured depth: 5,007' - 5,220' T V rti l d th ' ' ~~~` dr~ ~~~~~ rue e ca ep : 5,007 - 5,220 > ~ - Tubing: (size, grade, and MD) 3-1/2" N-80 4,961' -r Packers and SSSV (type and measured depth) Baker FH Packer 4,923' 12. Stimulation or cement squeeze summary: Marathon performed a Coil Tubing Clean Out to 5,197' (60') Mud Intervals treated (measured): Acid Stimulation on BC-2 well. A blend of HCL, HF Mud Acid & Ammonium Chloride was pumped into the Sterling formation in Treatment descriptions including volumes used and final pressure: stages. This resulted in a Wellhead pressure reduction of approximately 790 psi during injection. 13. Representative Daily Average Production or Injection Data. Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 0 - 1 1,419 psi Subsequent to operation: 0 0 - 1 635 psi 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run Exploratory ^ Development ^ Service Q Daily Report of Well Operations X 16. Well Status after work: Oil^ Gas ^ WAG ^ GINJ ^ WINJ ^WDSPL c~ ^~ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 308-457 Contact Kevin Skiba (907) 283-1371 Printed Name Kevin J. Skiba ~ Title Engineering Technician Signature - ~ Phone (907) 283-1371 Date February 11, 2009 V Form 10-404 Revised 04/2006 r F ki .k LQO~ ~ ~/ Submit Original Only • • Maradan operations Summary Report aQ~~ ~~~~ Well Mame: BEAVER CREEK 02 Daily Operations Report Date: 1121/2009 Job Category: R&M MAINTENANCE 2/HrSemmary MIRU pit liner, Fluid, flow back tanks, and choke opa SgrtTme E~tlTlne Der 0 Code AaW Code Siada TpMkCOtle Cammeet 13:00 14:00 1.00 SAFETY MTG AF Hold PJSM. Discuss alarms, muster area, and emergency response. scuss ASRC JSA. Make job assingments. Obtain SWP. 14:00 18:00 4.00 RURD EQIP AF ay Nner. Spot KCL tank. Spot MEOH tank. Spat flow back tank and gas uster. 18:00 18:15 0.25 SECURE LL AF Secure locatoor, for the night. Report Date: 1122/2009 Job Category: R&M MAINTENANCE 2lMrSrmmary MIRU BJ CoilTech. Install BOP'sw on WH and PTest. RD for the night. StartTlne EICTIne Dot o Cotle PYCtL Code opa 5~rrs TroWkCOdt Cammeet 07:30 08:30 1.00 SAFETY MTG AF Hold PJSM. Discuss alarms, muster area, and emergency response. scuss BJ JSA and specific job hazards. Obtain S'WP. At 11:581 f201U9 otify Mr. Jim Regg w/ AOGCC of pending BOP lest on BC-2. Witness was aived. ' 08:30 09:00 0.50 PREP LOC AF lectrician disconnects power to well house. Hold prelift meeting. Lift well ouse off WH. 09:00 12:15 3.25 URU OIL F ay iners. Spot and unload Coil equipment. RU to gas buster, choke w/ 2" and lines. RU coil equipment. Mixing 6% KCL. Call out Steam on Wheels u heal KCL. 12:15 15:30 3.25 URD OIL AF ock out injection pumps. Close wing valve. Close swab. Remove tree ap flg. PU BOP's and carry to well head. Steam on Wheels arrives. btains HJVP. Sign JSA's. Begin heating KCL tank. RU 2" iron to flow ross. MU 2" lines to choke manifold Lay suction hoses to MEOH. 15:30 19:15 3.75 TEST E AF unction test BOP's. Te P's. Swab leaking. Call GLM to grease swab slue. PTest surface iron. Test good. Test accumulator. GLM arrive rease swab. PT blinds and pipe rams. Test good. Install Dimple-on onnector on coil. Pull test to 20K. Good test. 19:15 19:45 0.50 ECLt3E LL AF en master and win valve. Reestablish,produced water infection, Wrap ree and flow line w! ~sulated blankets. Secure well head, equipment, and ocation for the might. Turn in permit. Sign out and leave location. Report Date: 7/238009 Job Category: R&M MAINTENANCE 2t MrSrmmary PU injector RIH to clean out 50' of fill. Tag fill ~ 5138'. Clean out to 5145'. Hit hard streak. Unable to penetrate. POOH for the night.PU injector RIH to clean out SO' of fill. Tag ftl ~ 5138'. Clean out to 5145'. Hit hard streak. Unable to penetrate. POOH for the night. StartTlne EatlTlne Der 0 Code WCW Cade opa Slada Tro~DkCOde Cammeet 07:30 08:30 1.00 SAFETY MTG AF Hold PJSM. Discuss alarms, muster area, and emergency response. Discuss BJ JSA and specific job hazards. Obtain SWP. 08:30 08:45 0.25 RLN~D COIL AF ock out injection m s. Close win valve and lock out. 08:45 09:45 1.00 RURD COIL AF art coil unit, pump truck, and support equ~ment Select BHA- Dimple on, 3' 1-314" weight bar,11 " x 1-314" ,and 5" x 1.92" nossle.. 09:45 11:15 1.50 RURD COIL AF U injector. MU BHA. Carry injector to WH. Begin loading coil wl KCL (27.3 bls) Experience severe plugging at 20 bbls 3000 psi. Shut down. epressure. Breaks back ~ 2500 psi. Continue pumping. Displace CTU. eturns mudd and black. Clears up after a couple bbls. SheN test to 500 si low/ High 3200 psi. Test good. Open swab. 1800 psi WHP. Acid wives on loc. S otti tanks. 11:1 S 13:24 2.15 RUNPUL COIL AF gin RIH ~ 50 fpm. Start pumping min rate. WHP 1800 psi. 13:24 13:42 0.30 RUNPUL COIL AF At 5066', begin fbwing well to flow back tank. WHP 2160 psi. Pressure bleeding off slowly. www.peloton.com Report Printed: 2i4/2009 • • ~~ Maradwn operations Summary Report ,~,,~, t~~~ ComPanY Well Name: BEAVER CREEK 02 SgrtTlne EeOTlne Derprn OptCOOe P.C1DIyCOtle ~a Sgda TroeDkCOtle Canmeet 13:42 17:00 3.30 RUNPUL COIL AF Tag up .5138'. Increase rate to 1 bpm. VNiP 1800 psi Pump pressure 2750 psi. Holding flow back rate approx 1 bpm. Pressure continues to i&II. 14:05 5013' WHP 43 psi. Pump rate 1-3l4 bpm ~ 2910 psi. 15:02 5140' WHP 188 psi. Pump rate 1-314 bpm ~ 3345 psi. 15:38 5142.6' WHP 100 psi. Pump rate 1-314 bpm @ 3179 psi. 16:15 5145 VvHP 92 psi. Pump rate 1-314 bpm ~ 31 SO psi. PUH. RIH 17:00 5145 No ro ress. 17:00 17:51 0.85 RUNPUL COIL AF OOH ~ 100 fpm. 17:51 17:51 RURD COIL AF OH. Close swab. Open to MEOH tank to freeze depress coil. Pump 30 bls. Lift injector off VvN. Install night cap. Unlock wing valve and line up ell for in'edion. Leto erator know that the well is his. 17:51 17:51 SECURE LL AF ut down all equipment. Secure location far the night. Report Date: 1124/2009 Job Category. R&M MAINTENANCE 2l HrSemmary PU Motor and mill to clean out 50' of fill. Tag fill ~ 5141'. Clean out to 5205' StartTlne EeGTlnt Der 0 CoOe ~ CoOt opa Sfaps Tro1Dk title Canmtet 07:30 08:30 1.00 SAFETY MTG AF old PJSM. Discuss alarms, muster area, and emergency response. iscuss BJ JSA and specific job hazards. Obtain SWP. 08:30 08:45 0.25 RURD COIL AF tick out in ection um s. Close win valve and lock out. 08:45 11:21 2.60 RURD COIL AF art coil unit, pump truck, and support equipment. Offload AIMM vac truck 'nto ttCL tank. Pull night cap. PU injector. PU 16' of lubicator. (All langed/hammer up connections.) 11:21 12:27 1.10 arty injector to WH. Begin displacing MEOH from cotl w/ ttCL (27.3 bbls). emove lubricator from VVFi. 12:27 13:33 1.10 RURD COIL AF U BHA: xternal CTC 2.25" x 14.5" CV 2.125" x 16.5" SS 2.125 " x 18.75 irc sub 2.125" x 12" HA 2.125" x 98" blade junk mRl 2.70" x 12" ell test to 500 si low/ Hi h 3200 si. low ressure leak. Re lace o-tin on i Te hell. 0 n wab. 2150 si V4HP 13:33 14:03 0.50 RUNPUL COIL AF qualize WHP 1900 psi. Begin RMi to 116'. WHP 100 psi. Bowen begins Baking. POOH to investigate. Ice in threads prevent~g threaded Bowen tom making up completely. Clean threads and make up again. Perform a eries of pressure tests. Tests good. Open swab. 14:03 16:03 2.00 RUNPUL COIL AF H w/ 2.70" 4 Bladed Junk mill. 16:03 18:21 2.30 MILL JUNK AF Tag up ~ 5141'. Increase rate to 1.3 bpm. Pump pressure 1200 psi. VNiP 30 psi. Mill at approx. 1 fpm. Drilling 10', then PUUH to circulate solids up tile. Mill to 5205'. PUH to WEG circulate 3-1 I2"tubing clear. Returns are ray. Seeing some solids. No more "oily" solids as seen the day before hile elfin out. Pulls les. 18:21 19:21 1.00 CIRC CFLD AF IH to 5200'. Pump bottoms up (45 bbls.). 19:21 21:21 2.00 RUNPUL COIL AF OOH ~ 100 fpm. 21:21 2221 1 .00 RURD COIL AF OH. Close swab. Open to MEOH tank to freeze depress coil. Pump 30 bls. Lift injector off WH. Install nighrt cap. Unlock wing valve and line up ell for injection. Attempt to release injection line pressure (1800 psi) to ell. WHP 0, but valve difficult to open all the way. Notify night operator. lowly pump warm produced water to warm valve and line. Open valve. et o erator know that the well is his. 22:21 22:51 0.50 SECURE LL AF Shut down all equipment for the night. Secure location. Turn in permit and leave location. www.peloton.com Report Printed: 214!2009 • • Malrathon laperations Summary Report ~.~i~ COmPanY Well Name: BEAVER CREEK 02 lMRGTM011 Report Date: 1/25/2009 Job Category: R&M MAINTENANCE 2a H r Srmmary PU Motor and 2.65" x 6.46" underreamer to clean out 60' of fill. Clean out from 5140' to 5160. PUH when well kicked to 375 psi WHP. In flowed 10 bbls. Cuttings bridged ~ 5130. Stalled motor. After circulating well clean. Continued milling 5130'to 5136'. Experiencing poor reaming performance. POOH. Underreamer damaged lost center cutter. Underreamer blades severely worn- Send to be rebuilt. StartTlne EedTlne Drr 0 Cote AYCaI Code Opa Sfatra TroebkCOde Canmeet 07:03 0 7:48 0.75 S AFETY MTG AF Hold PJSM. Discuss alarms, muster area, and emergency response. Discuss BJ JSA and specific job hazards. Obtain SUvP. 07:48 0 9:24 1.60 R URD COIL AF Start coil unit, pump truck, and support equipmerrt. Pull nigh cap. PU in ector. Be in dis lacin MEOH from col w/KCL 27.3 09:24 0 9:48 0.40 R URD COIL AF Carry injector to WH. Remove lubricator from WH. bbls). PU 16' of lubrcatar. Steam on Wheels arrives to heat KCL tank. 09:48 1 0:06 0.30 R URD COIL AF PU BHA: External CTC 2.25" x 14.5" DFCV 2.125" x 16.5" BOSS 2.125 " x 18.75 Circ sub 2.125" x 12" MHA 2.125" x 98" 2-5/8x 6.46" underreamer x 42.5" 10:DG 1 0:12 0.10 f il.HiD COIL AG Lock out injection ~uinps. Close veiny valve and lock out. 10:12 1 0:27 0.25 RURD COIL AF Shell test to 250 psi bw/ Hiph 1000 psi. low pressure leak. Test good. Open swab. 1500 psi WHP. Equalize WHP 0 psi. Well bleeds down quickly. 0:27 12:27 2.00 RUNPUL COIL AF RIH w! 2.-51'8" Underreamer. 2:27 19:42 7.25 MILL JUNK AF Begin underreaming to clean out 60' of fill. Clean out from 5140'to 5160. PUH when well kicked to 375 psi WHP. In flowed 10 bbls. Cuttings bridged ~ 5130. Stalled motor. After circulating well clean. Continued milling 5130 0 513 '. Experiencing poar reaming performance. POOH. Underreamer damaged lost center cutter. LOST IN WELL (2.65" ODx 1"approx.) Underreamer blades severe) worn. Send to be rebuilt. 9:42 20:42 1.00 RUNPUL COIL Circulate well clean. Shut down pump. Pull back up into 3-1112" csg. POOH. 20:42 21:42 1 .DO RURD COIL AF OOH. Close swab. Open to MEOH tank to freeze depress col. Pump 30 bbls. Lift injector off WH. Instaq night cap. Unlock wing valve and line up well for iri ection. O en valve. Let eratar know that the wdl is his. 1:42 22:12 0.50 SECURE LL AF Shut down aN equipment for the night. Secure location. Turn in permit and IEaVe locatlari. port Gate: 112612009 Job Category: R&M MAINTENANCE 2a FI r Semmary RIH wI underreamer. Unable to get by 5139'. Begin reaming ~ 5139. Ream to 5145' Very slow. POOH. PU mill in the morning to redrill pilot hole. S~rtTtne EedTlne Ou 0 Sldtia Troebk Canmee 9:D0 1 D:00 1 .00 SAFETY MTG AF Hold PJSM. Discuss alarms, muster area, and emergency response. Discuss BJ JSA and specific job hazards. Obtain SWP. 0:00 12:12 2.20 URD OIL F Start coil unit, pump truck, and support equipment. Puff night cap. PU injector. Carry injector to WH. Begin displacing MECli from coil w/KCL 27.3 bbls 2:12 12:24 0.20 URD OIL F Remove lubricator from WH. bbls). PU 16' of lubicator. 12:24 12:36 0.20 RURD COIL AF PU BHA: External CTC 2.25" x 14.5" DFCV 2.125" x 16.5" BOSS 2.125 " x 18.75 Circ sub 2.125" x 12" MHA 2.125" x 98" Underreamer 2-518" OD x 6.46"x 42.5"L 2:36 12:42 0.10 URD COIL AF Lock out injection pumps. Close wing valve and lock out. 2:42 12:57 0.25 RURD COIL AF Shell test to 250 psi low/ High 1700 psi. Test good. 2:57 14:57 2.00 RUNPUL COIL AF w - x n erreamer. www.peloton.com Report Prirrted: 21401009 • Marathon t~perations Summary Report sp~~ ~~~~ Well Name: BEAVER CREEK 02 oa SgrtTme ErGTlne Drr 0 COtlt AuLW Cbtl2 S7ads TrorbkCaOe Canmert 14:57 17:27 2.50 MILL JUNK AF Start underreamer ~ 5080'. Mill down to 5139' and stall out motor. Shut down pumps to allow underreamer blades to restract. Attempt to slide down thru tight spot as we did last night. Tags 5140'. Begin underreaming to clean out ~ 5138'. Clean out from 5145'. Drill 7' in 2-1 C2 hrs. Elect to POOH and PU 2.70" unk mill. 17:27 18:27 1.00 RUNPUL COIL Circulate well clean. Shut down pump. Pull back into 3-1112" csg. POOH. 18:27 19:27 1.00 RURD COIL AF OOH. Cbse swab. Open to MEOH tank to freeze depress coil. Pump 30 bbls. Lift injector off WH. Install night cap. Unlock wing valve and line up well for injection. Attempt to release injection line pressure (1800 psi) to weU. WHP 0, but valve difficult to open atl the way. Notify night operator. Slowly pump warm produced water to warm valve and line. Open valve. Leto erator know that the well is his. 19:27 19:57 0.50 SECURE LL AF Shut down all equipment for the night. Secure location. Turn in permit and leave location. Report Date: 1!272009 Job Category: R&M MAINTENANCE 2l Mr Summary IH w/ 2.70" 4 Blade junk mill. Begin milling ~ 5139. Mill to 5200' in 2-1 !2 hours. Circulate holes clean. POOH. Perform BOP Test. PU underreamer! in the morning to open up pilot hole. SiartTlne ErOTlne Drr D Cotle AAaI COOe opa Stads Tro~Dk Canme~t 07:30 08:00 0.50 SAFETY MTG AF Hold PJSM. Discuss alarms, muster area, and emergency response. Discuss BJ JSA and specific job hazards. Obtain SWP. 06:00 10:36 2.60 RURD COIL AF Start coil unit, pump truck, and support equipmend. Cut 120' of pipe. Offload vac truck into KCL tank. Pull night cap. PU injector. Carry injector o WH. Be in dis lacin MEOH from coil w/KCL 27.3 bbls . 10:36 11:42 1.10 RURD COIL AF Remove lubricator from WH. PU 16' of lubricator. Install new coil connector and puN test to 20K. Test good. 11:42 11:57 0.25 RURD COIL AF Lock out injection pumps. Close wing valve and lock out. 1:57 12:42 0.75 RURD COIL AF PU BHA: External CTC 2.25" x 14.5" BOSS 2.125 " x 18.75 Circ sub 2.125" x 12" MHA 2.125" x 96" 4 blade junk mill 2.70" x 12" Shell test to 500 si bwl H' h 2500 si. Test ood. Try to open swab. Frozen. Put heater on d to thaw. en swab. 2050 si WHP 2:42 12:48 0.10 RURD COIL AF Give 24 hr notice to Mr. Jsn Regg, AOGCC of pending BOP Test. Witness waived. ~-~- 2:48 14:03 1.25 RUNPUL COIL AF eed well pressure. RIH w/ 2.70" 4 Bladed Junk mYl. 4:03 16:48 2.75 MILL JUNK AF Tag up [aP 5138'. Increase rate to 1.7 bpm. Pump pressure 2200 psi. WHP 30 psi. Mill out solids. MiN to 5205'. PUH to WEG circulate 3-1 t2"tubing clear. Returns are black scaly looking solids. 6:48 17:33 0.75 CIRC CFLD AF RIH to 5200'. Pump bottoms up s.. owly pull u into tubing tail. 7:33 18:33 1.00 RUNPUL COIL AF POOH from tubing tail ~ 100 fpm. 8:33 19:48 1 .25 RURD COIL AF OOH. Close swab. RU GLM grease crew to grease swab. K leaked durrin first BOP Test. Standback 16' lubricator. Carr in'edor back to Wli. 9:48 20:00 0.20 RURD COIL AF Open to MEOH tank to freeze depress coil. Pump 30 bbls. Lift injector off . Install night cap. Unlock wing valve and line up well for injection. Stand back injector. Install tree cap, 0:00 21:18 1 .30 TEST ROPE AF Function test BOP's. Test i e rams 250 Iow14500 i Test good. Test blind rams 250 low/4500 psi. PTest surface iron. Test good. Test accumulator. Test ood. 1:18 21:48 0.50 SECURE LL AF Shut down all equipment for the night. Secure location. Turn in permit and leave location. www.peloton.com Report Printed: 2142009 ~~^^ Marathon operations Summary Report ,ryT,~, SQ~~ ~nPe~'Y Well Name: BEAVER CREEK 02 Report Date: 7128!2009 Job Category: R&M MAINTENANCE 21 H r Srmmary PU Motor and 2.65" x 6.46" underreamer to clean out 60' of fill. Clean out from 5140'to 5200'. Underreamer blades would not retract. Circ sub, Extreme motor, and 2-518" underreamer lost in hole. Parked on bottom 5200'. StdrtTme ErtlTlne Drr 0 Cotl! AicW Cotle opa St3pa TrorDkCOOr Canmert 07:30 08:00 0.50 SAFETY MTG AF Id PJSM. Discuss alarms, muster area, and emergency response. 'scuss BJ JSA and specific job hazards. Obtain SWP. 08:00 09:36 1.60 RURD COIL AF art cal unit, pump truck, and support equipment. Pull night cap. PU 'H'ector. Be in dis lacin MEOH from coil w/KCL 27.3 09:36 10:00 0.40 RURD COIL AF arry injector to WH. Remove lubricator from WH. bbls). PU 16' of ubicator. Steam on Wheels arrives to heat KCL tank. 10:00 10:36 0.60 RURD COIL AF U BHA: xternal CTC 2.25" x 14.5" CV 2.125" x 16.5" SS 2.125 " x 18.75 Circ sub 2.125" x 12" MHA 2.125" x 98" 2-5/8x 6.46" underreamer x 42.5" 10:36 10:42 0.10 RURD COIL AF Lock out injection pumps. Close wing valve and lock out. 10:42 10:57 0.25 RURD COIL AF Shell test to 250 psi local High 1000 psi. Test good. Open swab. 1200 psi P. Equalize WHP 0 psi. Well bleeds down quickly. 10:57 12:33 1.60 RUNPUL COIL AF IH cal 2 -518" Underreamer. 12:33 17:03 4.50 MILL JUNK AF gin underreaming to clean out 60' of filt. Clean out from 5130'to 5197'. ulling up hole every 15' to circulate out fill. Stall motor 5 times while earning. Genlle stalls pressure seldom went above 3400 psi. Noticed ement solids in returns from 5197'. 17:03 18:18 1.25 H circulate well clean. Shut down pump. Pull back up into 3-112" tubing. ull up to 13K. 18:18 21:33 3.25 RUNPUL COIL abl ~ o ubin tail. RIH to 5000'. Start pump to attempt to wash nderreamer clean. Perform this operation multiple times w/o success. Pul into tubing tail multiple times, pulling 22K, 32K, 36K twice, and 37K. Pull into tubin tail w1 motor turner ant 1 b m to no avail. 21:33 22:03 0.50 cess w/underreamer. Elect to Run t to bottom end " ark" lt there. op 314" ball to function BOSS hydraulic disconnect. Pumps ball to isconnect sub. Pressure uo to 4200 psi to actuate disconnect. Pull free nd POOH. 22:03 22:51 0.80 RURD COIL AF OOH. Close swab. Open to MEOH tank to freeze depress coil. Pump 30 bls. Lift injector off WH. Install night cap. Unlock wing valve and line up well for injection. Open valve. Let operator know that the well is his. 22:51 23:21 0.50 SECURE LL AF Shut down all equipment for the night. Secure location. Turn in permit and save location. Report Date: 1/3112009 Job Category: R&M MAINTENANCE 2l H r Srmmary RU to jet csg clean. Pump 3000 gals.15% HCL13% HF acid. 18 bbls.3% Amoniun CI2 spacers. Displace wI 6%KCL. StartTlne ErtlTlne Orr PiL`ID Cotle opc Stada T r k Canmert 07:30 08:30 1.00 SAFETY MTG AF kf PJSM. Discuss alarms, muster area, and emergency response. scuss BJ JSA and specific job hazards. Obtain SVVP. 08:30 10:30 2.00 RURD COIL AF art coil unit, pump truck, and support equipment Select BHA- Dimple on, 3' x 1-314" weight bar, 11" x 1-314" ,and 5" x 1.92" nossle. Install Didmple on nd ull test to 21 K. Test od. 10:30 11:21 0.85 RURD COIL AF U injector. MU BHA. Carry injector to WH. PTest shell to 25013200 osi. est good. Break circulation wI MEOH. Begin displacing MEOH to MEOH ank. 11:21 11:27 0.1 D RURD COIL AF ock out injection pumps. Close wing valve and lock out. 11:27 13:03 1.60 RUNPUL COIL AF teed down WHP 800 si . Be in RIH 50 f m. Start um in min rate. 13:03 15:09 2.10 RUNPUL COIL AF oft tag ~ 5190'. PUH begin jetting 5000'to 5190'. Pumping 1 .5 bpm 1600 si WHP 8 psi. Pump 150 bbls 1.5 bpm jetting perforations. Pump 7-112 bbls HEC-10 pill. Displace w175 bbls 6% KCL. Gel back to surface. Very clean. 15:09 16:24 1.25 Pump second HEC-10 pill. Displace w175 bbls 6%KCL. Pill came back clean. www.peloton.com Report Prirrted: 2/401009 • ~-^^ Marathon operations Summary Report ~~ ~Qil Compalny Well Name: BEAVER CREEK 02 S1artTtne EetlTNe Der D C AiCLI C v~ Stada T ebkC Canmeet 16:24 16:42 0.30 SAFETY MTG AF Hold Pre acid job safety meeting. Discuss emergency procedures, location of eye wash bottles and station, topical ointment, water shower,and muster rea. 16:42 18:57 2.25 ump: 20 bbls 3% Amonium Chloride water 75 bbls 15% HCL 13% HF Acid 16 bbls 3% Amonium chloride water 60 bbls 6% KCL displacement. 18:57 20:57 2.00 RUNPUL COIL AF OOH Laa 100 fpm. At surface pump acid rinsate down hole. 20:57 23:57 3.00 RURD COIL AF OH. Close swab. Attempt to displace coil w/ N2. Unable to get N~ pump primed and pumping. Open to MEOH tank to freeze depress coil. Pump 30 bls. Lift injector aff WH. Install night cap. Unlock wing valve and line up well for in action. Leto erator know that the well is his. 23:57 00:12 0.25 SECURE LL AF Shut down all equipment. Secure location for the night. Report Date: 2M2009 Job Category. R&M MAINTENANCE 2l M r Semmary RD coil unit. Coil plugged, and BOP's frozen. Thaw injection line and tree. StartTlne EedTlne Orr D ade ACtlI C Opc 3~dL TroebkCOtle Canmeet 10:00 11:00 1.00 SAFETY MTG AF Hold PJSM. Discuss alarms, muster area, and emergency response. Discuss BJ JSA and specific job hazards. Obtain SVVP. 11:00 17:00 6.00 RURD COIL AF Start equipment. -20 degree F. Equipment V cold. RD acid hose to tanks. ul off acid tanks. LD lubricator. Wait~g on N2 pumper to displace coil. arr i 'actor to V4ti. unable to um .Sus d coiN frozen. Coil end lugged and frozen. BOP's frozen, as well as the wet head. Thaw 'n action line. Return to roduction for injection. 17:00 18:00 1.00 RURD COIL AF ew member injures hand cranking up light tower. Report minor injury to ate Barrat and mana ement. Shut down for the night. 18:00 18:00 SECURE LL AF cure well and bc. Turn in ermit and leave location. Repori Date: 2/2x2009 Job Category: R&M MAINTENANCE 2e H r Semmary RD coil unit. Well head and BOP's frozen. Thaw and remove from WH. S6rtTlne HOTIne Der D Code Code a Start TroebkCode Caameet 10:00 11:00 1.00 SAFETY MTG AF ki PJSM. Discuss alarms, muster area, and emergency response. scuss BJ JSA and specific job hazards. Obtain SUVP. 11:00 17:00 6.00 RURD COIL AF art equipment. -20 degree F. Equipment V cold. Start heaters. Thaw rozen BOP's and well head. RD 2" hard line. Remove BOP's from well ead. Install tree cap. Install well house. RD remainder of "iron and choke skid. PU drip liners and move out equipment. Haul off water and solids rom work and flow back tanks. Release Port a potty. Call out electrician to estore ower to well house. Turn ad over to o erations. 17:00 17:00 SECURE LL AF Secure well and loc. Turn in permit and leave location. www.peloton.com Report Printed: 2142009 50-133-20021-00-00 :rtv Des: FEDA - 028118 15' AGL (155' KB Elevation) Date: 7/13/1967 Ite: 11 /9/1967 eleased: 09:OOhrs 12/26/1967 B~~~ Pad 2 (Injection Well) 590' FNL, 1,979' FEL Sec. 3, T6N, R10W, S.M. Conductor 20" H-40 94 ppf ToD Bottom MD 0' 280' TVD 0' 280' CmUw 525 sacks Perforations: Sterling B-1: 5,007'-5,028' 5,032'-5,052' Sterling B-2: 5,125'-5,140' Sterling B-3: 5,155'-5,220' Isolated Perforations: Sterling B-3a: 5,230'-5,244' squeezed B-3a: 5,263'-5,265' Sterling B-4: 5,324'-5,344' CTU Clean out to 5,197' 3,000 gal, 15% HCL / 3% HF acid job (1/30109) 2-5/8" x 6.46" underreamer, 2-1 /8" Motor, and circ sub, 14' long @ 5,197' (1/28/09) Cement Cap @ 5,197' Cement Retainer @ 5,221' Fill @ 5,132' SLM (11/11/01) / c ;!~ CC J~ ~L. ~ ~ ~ c r '~ 7' Liner stub ' @ 5,268' 7" liner shoe @ 15,439' 5" liner shoe @ 15,697' TD = 15,697' MD &TVD 13-3/8" N-80 & J-55 74 ppf ToD Bottom MD 0' 2,211' TVD 0' 2,211' Cmt/w 2,000 sacks ltermediate 40 ppf 9-5/8" N-80 & S-95 43.5 ppf 47 ppf Too Bottom MD 0' 8,835' TVD 0' 8,835' Cmt w/ 1,370 sacks Production Liner 29 ppf 7" N-80 & P-1 10 32 ppf ToD Bottom MD 5,268 15,439' TVD 5,268' 15,439' Cmt w/ 650 sacks Liner 5" N-80 18 ppf FJ Hydrill Top Bottom MD 15,415' 15,697' TVD 15,415' 15,697' Cmt w/ 41 sacks Production Tubing 3-1 /2" N-80 9.2 ppf Otis XA circ sleeve 4,889' Baker FH hyd packer 4,923' Baker WL entry guide 4,961' Well Name & Number: Beaver Creek #2 Class II Disposal Well Lease: Beaver Creek Unit, Pad 2 County or Parish: Kenai Penisula Borough State/Prov.: Alaska Date Completed: RKB: 15' Country: USA Angle/Perfs: Angle @ KOP and Depth: 0° KOP TVD: Ground level: 140' Revised by Mike Sulley Last Revision Date: 2/3/2009 ~ c C ~ C ~ r- ~ ~_ ~jX'1 c BC 2 -Monthly Injection Repo~TD#167-026 -January 2009 • Regg, James B (DOA) From: Miranda, Kyle [kmiranda@marathonoil.com] Sent: Monday, February 02, 2009 11:34 AM To: Regg, James B (DOA) '~ ~ ~`1t~~ Cc: Ibele, Lyndon; Walsh, Ken; Dammeyer, Michael D. Subject: BC 2 -Monthly Injection Report PTD#167-026 -January 2009 Attachments: BC2 Jan 2009 Injection Summary PTD167026.ZIP BC 2 -Injection Summary PTD167-026 -January 2009 -Marathon Oil Company Page 1 of 1 ~ 16-1- Uzi Enclosed is the Beaver Creek 2 Injection Summary PTD167-026 for January 2009, submitted monthly via email Quick Summary: Everything remains within the guidelines, that is: 1 The Inner Annulus Pressure has remained below 1000 si `~ p 9~ 2) No communication to the Outer Annulus has been realized. 'f 3) No OA or IA pressure bleeds were performed. Please note: - Beginning 1121109 cleanout of the wellbore and acid stimulation was performed to reduce overall injection pressure - Injection was still operational, although the volumes were slightly reduced during this period - The work was completed on 1131/09 and initial analysis indicates the job was successful in reducing injection pressure :i - in only two days of analysis, injection pressures are 1800 psi, approximately 600-700 psi lower than before the job Any questions or concerns, please do not hesitate to call or email. Kyle Miranda Production Engineer I Marathon Oil Company-Alaska Asset Team ~~~~~~ DEB ~ ~ 2DD9 907-283-1370 (office) 907-394-8271 (cell) Items included in the BC 2 report for January 2009: 1. Flowrate (BPD} 2. Inner Annulus Pressure (psig) (must stay below 1000 psig) 3. OuterAnnu/us Pressure (psig) (must notify the AOGCC if any communication is realized) 4. Tubing Pressure (psig) 5. Volume Injected (BPD) 6. All OA and IA Pressure Bleeds «BC2 Jan 2009 Injection Summary PTD167026.ZIP» 2/3/2009 ^ Flowrate (BPD) • Tubing (psig 1440 -^- TOW Inner nnulus (psig) 1320 -- ---- - -_ - - -- ^ In11~ected Volume (BPD) -+-TOW Tubing Pressure (psig) - 3000 ----- ------ - f ~ - --- 2750 • _ • - ___ .._. --------•_ .._~ 2500 • ~ -- _ _ ---- _ _ 2250 • • • • - - -_ _ _ ._ • - ~~ --- .. _ ___ -_ 2000 640 -- --- - _ ___._ _ - -~ - ~-- ~- ~~_~._ ~~ ~ - ! - - ~ .~• 1750 •- ~~ ~ ~ Q 720 _ - ^ -- _ - - - -_ ~ _ _ - -~. __ _ . - - 1500 ^ ^ ^ ^ ~ ^ ^ ^ ^ } • ~ v, 600 - ~~~ ~~~ ~~~~~~,~~ ~~~~ ~ ~~ ~ i ~ -~ + r 'i 1250 a 1 ~ .~ • 480 ~_ - _ - - - _ _ _ .~- • __ _ ~ 1000 e • • 360 _ __-_ ---_---___ _ _ _ _ _- __ - __ _-___ _ _ ____ __ _- -_ ______ -_ __ ~ _ _ _ - _ __ ^ _ __ __~ 750 • • • • 240 -- _ - - - - - -- _ _ --- _ _ _ - - - - --_ _ __- - • -_ _ _ - - - - - - ~ --- 500 ~~• ~ 120 ~ . ^ - _ _^--~ --~ - __ _~ --^_ - -^-_ r ~ _ _ - __ ^ r - ^ ^. ~ • ---~ __.__..__._..__ 250 ^ ^ ^ ~^ ^ o ,._ - _ - -- -----,_.. ~.,- _ o ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ .~ .~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ N N N N ~ N W ~ CJ1 ~ v OD ~ ~ ~ ~ ~ ~ ~ -~~ ~ ~ ~ N N N N N N N N N N W W ~ N W ~''~ N N N N N N N N N O ~ N W ~ (~ ~ \ OD ~ O ~ N W A (\J1 ~ Vim. 00 C`O O ~ N N N ~ O O O O O O O O O N N N N N N N N N N N N N N N N N N N N N N O O O N O O O O O O O O O O O O O O O O O O O O O O O O O O O O O O O O O O O (fl Cfl Cfl CO Cfl O CO CO CO O O O O O O O O O O O O O O O O O O O O O O Cd c0 Cfl ~ CO CO Cfl Cfl C~ CO Cfl CO Cfl CO Cfl to CO CO fD C~ CO Cfl Cfl CO CO CO Time ~~l C lP~~, ate- ~ c,~c~l s~~~--~;,., BC 2 Jan 2009 Injection Summary Outer Annulus (psi ) • Inner Annulus (psig • ~~tn,~~ 2~~~ ~55iN~e Sleds Inner Annulus Pressure Bleeds Date Time Pressure (before) Pressure (after) None None None None Outer Annulus Pressure Bleeds Date Time Pressure (before Pressure after None None None None BC 2 -Monthly Injection Report P~#167-026 -December 2008 Page 1 of 1 Regg, James B (DOA) 16~ - ~~ From: Miranda, Kyle [kmiranda@marathonoil.comJ Sent: Thursday, January 08, 2009 2:02 PM ~~ To: Regg, James B (DOA) 1\ Cc: Ibele, Lyndon; Walsh, Ken; Dammeyer, Michael D. Subject: BC 2 -Monthly Injection Report PTD#167-026 -December 2008 Attachments: BC2 Dec 2008 Injection Summary PTD167026.ZIP BC 2 -Injection Summary PTD167-026 -December 2008 -Marathon Oil Company Enclosed is the Beaver Creek 2 Injection Summary PTD167-026 for December 2008, submitted monthly via email. Quick Summary: Everything remains within the guidelines, that is: 1) The Inner Annulus Pressure has remained below 1000 psig. 2) No communication to the Outer Annulus has been realized. ''~ 3) No OA or IA pressure bleeds were performed. ~ Any questions or concerns, please do not hesitate to call or email. Kyle Miranda Production Engineer I Marathon Oil Company-Alaska Asset Team ry 907-283-1370 (office) ~'~~~~~~ ~EB ~- «~ L~v~ 907-394-8271 (cell) Items included in the BC 2 report for December 2008: 1. Flowrate (BPD) 2. Inner Annulus Pressure (psig) (must stay below 1000 psig) 3. Outer Annulus Pressure (psig) (must notify the AOGCC if any communication is realized) 4. Tubing Pressure (psig) 5. Volume Injected (BPD) 6. All OA and IA Pressure Bleeds «BC2 Dec 2008 Injection Summary PTD167026.ZIP» 1 /9/2009 • • (6isd) a~nssa~d °o°c~ °o ~°r~ °o ~°n °o°r~ °o 0 0 0 O I~ In N O ~ ~ N O ~ O Lf') M N N N N r- ~ ~'- ~ ~ ~ N O ~---- - 12/31 /2008 • ' ^~ _ • 12/30/2008 ~, ~ I 12/29/2008 n • o -- ~/ ~' ~ '' • k 12/28/2008 m ~ M~~r ^~ ~ I• 12/27/2008 ~~ ~ ~ ~ ~ , ~ ~ • ~ 12/26/2008 i ^~ ^ ~ ~ i ,,~ ! 12/25/2008 ~ ~ ; ~ ^ • ~ 12/24/2008 v , • ~ ~ .~? p ~ 12/23/2008 c ~ ( ~ ~' • 12/22/2008 ^+ ' I ~,' ' • 12/21 /2008 ~: ~ i ~ ""~'~~ ,I ~ ~ •~ 12/20/2008 ~ ~ ~ • ~ • 12/19/2008 N ~ •~ 12/18/2008 g n j ~ ~'I • 12/17/2008 ~ •_ ~ ~ ~ i• 12/16/2008 ~ ~ 12/15/2008 N ~ Q i ' ~ ~ ' • 12/14/2008 ... N i ~~ c ~ ~ j I ~ • 12/13/2008 v ~ ~ , ~ * ~ ^ ~ j ^ 12/12/2008 00 ^ ' ^ ^~ ~ • 12/11 /2008 -- • ~ ~ ~ • 12/10/2008 rn ~ i g ', ^ ~ ~ ! • ! 12/9/2008 ~ '~ ! ~• ~ • 12/8/2008 i ^ 12n/loos ^. ~ m ~~, ~ ' Q ~ ^ ^ ~ ^ N! * 12/6/2008 3 c ~ ^ • ~ ~ • 12/5/2008 o~p ~~' ~ ~ ~ ~ ~ r 12/4/2008 I • • ~' ' ~ 12/3/2008 ~~ ^ -- ~ ', • ~ • 12/2/2008 ~~~~ ~ -- ~~ 12/1/2008 0 0 0 0 0 0 0 0 0 0 0 0 0 ~ N O 00 (fl ~1 N O 00 (O ~ N ~ M N O O O ~ CO ~ M N r- ~ ~ ~ ~ lade) awn~on pue a;e~nno~~ ~CC~w~- Zt~() o ~ssu,,~ ~bl~~s Inner Annulus Pressure Bleeds Date Time Pressure (before) Pressure (after) None None None None Outer Annulus Pressure Bleeds Date Time Pressure before) Pressure after None None None None • • ~~ ~~ }, ~~ ~ ~ ~ I ~~~ ~Y ( ~ ~ 1. ~~~ ~~ f ~ ~~ t ~,~ "~~ ~ ~yl,~~ t~ 1^~ ~ [_~ ~~-~~ ~-~}~ ~ ~~ ~~---~.~ ~ SARAHPALIN, GOVERNOR ~-7~ OIL A1~TD GAS %~ 333 W. 7th AVENUE, SUITE 100 CONSERQA'I`IOl~T CO1~II-iISSI01~ ,' ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 Kyle Miranda ~' FAX (907) 276-7542 PE Marathon Oil Company PO Box 1949 5 ° _ r F~~~~~~~~ iJ ~ ~ ~ ~ 20(l~ ~!p Kenai AK 99611-1949 '~ ~~ f Re: Beaver Creek Field, Undefined Disposal Pool, Beaver Creek Unit #2 Sundry Number: 308-457 Dear Mr. Miranda: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, Daniel T. Seamount, Jr. `, Chair DATED this 1 ~ day of December, 2008 Encl. • M Marathon MARATHON Oil Company December 17, 2008 Mr. Tom Maunder Alaska Oil & Gas Conservation Commission 333 W 7th Ave Anchorage, Alaska 99501 Reference: 10-403 Application for Sundry Approvals Field: Beaver Creek Unit Well: Beaver Creek #2 Dear Mr. Maunder • Marathon Oil Company Alaska Asset Team P.O. Box 1949 Kenai, AK 99611 Telephone 907/283-1371 Fax 907/283-1350 Enclosed please find the Application for Sundry Approvals, 10-403, for BC-2 well. BC-2 is a waste water injection well that has been experiencing increased injection pressures over the past three months. Marathon requests permission to perform a mud acid treatment after removing approximately 50' of fill with coil tubing. Please contact me at (907) 283-1371 if you have any questions or need additional information. Sincerely, rli~~' Kevin J. Skiba Engineering Technician Enclosures: 10-403 Application for Sundry Approvals Work Scope Procedure Current Well Schematic cc: AOGCC Houston Well File Kenai Well File KJS JKM ~/ ~ ~~~~ STATE OF ALASKA /~/~~" ALA OIL AND GAS CONSERVATION COM~ION ~ '\~~ 0~ APPLICATION FOR SUNDRY APPROVALS~~a ~~~ ~~~w 20 AAC 25.280 1. Type of Request: Abandon ^ Suspend ^ Operational shutdown^ Perforate Waiver ^ Other ^~ Alter casing ^ Repair well ^ Plug Perforations ^ Stimulate ^~ ~ Time Extension ^ CT Cleanout & ~ Change approved program ^ Pull Tubing ^ Perforate New Pool ^ Re-enter Suspended Well ^ Acid Stimulation 2. Operator Name: Marathon Oil Company 4. Current Well Class: 5. Permit to Drill Number: Development ^ Exploratory ^ 167-026 - 3. Address: p0 Box 1949 Stratigraphic ^ Service ^ 6. API Number: Kenai Alaska, 99611-1949 50-133-20021-00-00' 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: Spacing Exception Required? Yes ^ No ~ Beaver Creek Unit #2 9. Property Designation: 10. KB Elevation (ft): ~ 11. Field/Pool(s): ~~ ~ ~ ~v~i:~ FEDA028118 ~ 155' KB(15' AGL) Beaver Creek Field / S g Pool 12. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): _ / Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 15,697' ~ 1597' - 1/N~~/'~ ~ 5,197' 7,890' 5,197' NA Casing Length Size MD TVD Burst Collapse Structural 265' 20" 280' 280' Conductor Surface 2,196' 13 3/8" 2,211' 2,211' 3,450 psi 1,950 psi Intermediate 8,820' 9 5/8" 8,835' 8,815' 6,330 psi 3,610 psi Production 10,171' 7" 15,439' 15,439' 8,160 psi 7,020 psi Liner 258' 5" 15,697' 15,697' 10,140 psi 10,490 psi Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 5007'-5028'/5032'-5052' 5007'-5028'/5032'-5052' 31/2" N-80 4,961' 5125'-5140'/5155'-5220' 5125'-5140'/5155'-5220' Packers and SSSV Type: Packers and SSSV MD (ft): Baker FH Packer 4,923' 13. Attachments: Description Summary of Proposal ^ 14. Well Class after proposed work: Detailed Operations Program 0 BOP Sketch ^ Exploratory ^ Development ^~ Service ^~ 15. Estimated Date for 16. Well Status after proposed work: Commencing Operations: January 1, 2009 Oil ^ Gas ^ Plugged ^ Abandoned ^ 17. Verbal Approval: Date: WAG ^ GINJ ^ WINJ ^ WDSPL Q Commission Representative: 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Kevin Skiba (907) 283-1371 Printed Name Kyle Miranda Title Production Engineer Signature Phone (907) 283-1370 Date December 17, 2008 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: ~ ~ 5 Plug Integrity ^ BOP Test ~ Mechanical Integrity Test ^ Location Clearance ^ Other: _g Subsequent Form Required: '~~~\ APPROVED BY ' ~~ Approved by: COMMISSIONER THE COMMISSION Date: .:~ Form 10-403 Revised 06/2006 ~ ,~ F a ~ t ! ~, I L~ 1 Submit in Duplicate MARATHON • December 10, 2008 Marathon Oil Corporation Field: Beaver Creek WBS: W0.09.19220.EXP.001 BC 2 History: Produced water from BC field is injected into Sterling B-1, B-2, and B-3 zones. Injection pressure has increased 370 psi since August 2008 (from 2200 to 2570). Average flowrate is 100 bpd and 600 bpd at times of injection. The most recent acid stimulation on September 10, 2008 yielded no significant reduction in surface pressure. There is ~50' of fill covering the B3 perforations. Well Configuration: The wellbore is constructed with 3 1/2", 9.2 ppf tubing in 9-5/8" casing. Tree flange connection is 4-1/16" lOK. - Otis XL Ball Valve Nipple at 483' KB and Otis XA Circ Sleeve at 4889' - Tubing tail at 4961' and minimum ID is 2.75". - Tagged fill at 5152' KB on 8/10/2008 with a 1.75" bailer Top of cement plug at 5197' MD Obiectiye: Cleanout ~50' of fill down to top of cement plug at 5197'. Follow the cleanout with 15% HCL acid stimulation of the Sterling B1-B3 perforations to improve infectivity and reduce wellhead pressure. CT Cleanout Procedure: 1. Make arrangements with ASRC to lay liner and berm around flowback equipment. Deliver diesel fueled man-lift, two light towers, and frost fighter heater. Deliver MOC flowback tank, gas buster, and 2" SK choke skid to location. Deliver clean Rain-for-Rent fluid tank and fill with 500 bbls of 6% KCL water. Deliver 50/50 methanol water tank to location. Steam on Wheels to heat tanks. 2. Call out crew to RU choke, chicksan, gas buster, and open top tank. RU BJ CoilTech choke manifold and l0u filter pod unit. 3. MIRU ASRC crane and BJ CoilTech with 1-3/4" CT and BJ fluid and nitrogen pumps. NOTE: Tree flange connection is 4-1/16", lOK. Hold PJSM to discuss potential hazards and operational plan. 4. Pressure test BOP's with 50/50 methanol water to 250/4500 psi. 5. RIH w/ wash nozzle pumping filtered water through coil tubing at 0.3 BPM minimum rate to 5100' KB. Increase filtered water pump rate to 2 BPM and continue running in hole and clean out fill from last tag depth of 5152' to top of cement at 5197' KB. Monitor returns for solids. Also monitor return fluid rate compared to pump rate. If necessary, drop fluid rate to 1.5 BPM and add nitrogen at 300 scfin. Adjust fluid and nitrogen rates as necessary to maintain. full returns. When on bottom, circulate two bottoms up catching samples for analysis once the first bottoms up arrives at surface and at the end of the first circulation. 6. Leave coil in hole, acid to be spotted down in coil. Acid Stimulation Procedure: 1. MIRU BJ acid transport and enclosed fluid pump. Call out vac truck to deliver 500 bbl filtered water to source tank. 2. Hold PJSM to discuss potential hazards and operational plan. Review MSDS sheets of all chemicals present and have appropriate PPE donned. Person in charge to ensure that the Intro-Company Waste Manifest (ICWM) is properly filled out and signed for each hazardous product to be transported. Person in charge will also make every effort to fully utilize the entire volume of hazardous product downhole in the well. 3. Connect lines to pumps. BOP's tested at 250/4500 psi with 50/50 methanol water. Maximum surface pressure not to exceed 2900 psi during acidizing operations. 4. Pump acid treatment down coiled tubing as follows, monitoring pressure and rates: Stage.. Treatment Volume al] Volume bbl5j Pump Rate [b m] 1 3 % Ammonium Chloride 750 18 0.5 - 2.0 2 15% HCL : 3% HF Mud Acid 3000 71 2.0 3 3% Ammonium Chloride 750 18 2.0 4 6% KCL water flush 2577 61 2.0 5. RDMO BJ Services acid pumping equipment and reinitiate produced water injection through BC facilities. Closely monitor rates, volumes, and surface injection pressures. 6. Please call Kyle Miranda at 907-394-8271 (c) or 907-283-1370 (w) with questions and results. CONTACTS Ken Walsh: Lyndon Ibele: 907-283-1311 (w) 907-394-3060 (c) 907-565-3042 (w) 907-748-2819 (c) Kyle Miranda: 907-283-1370 (w) 907-394-8271 (c) KGF Operators 907-283-1305 Clyde Scott: 713-296-2336 (w) BC 2 CT Cleanout and Acid Stim -Kyle Miranda 12/16/2008 2:29:16 PM nit #: 167-026 #: 50-133-20021-00-00 ~erty Des: FEDA - 028118 15' AGL (155' KB Elevation) d Date: 7/13/1967 )ate: 11 /9/1967 Released: 09:OOhrs 12/26/1967 Sterling B-1: 5,007'-5,028' 5,032'-5,052' Sterling B-2: 5,125'-5,140' Sterling B-3: 5,155'-5,220' Isolated Perforations: Sterling B-3a: 5,230'-5,244' squeezed B-3a: 5,263'-5,265' Sterling B-4: 5,324'-5,344' B~~~ Pad 2 (Infection Well) 590' FNL, 1,979' FEL Sec. 3, T6N, R10W, S.M. ~ c ~ ~ ~ c ~ c Fill @ ~ 5,132' SLM -T (11/11/01) t~ ~ t-, Cement Cap @ 5,197' ~ C Cement Retainer @ 5,221' ~ ~ ~ c C T Liner stub 5,268' . 7" liner shoe @ 15,439' 5" liner shoe @ 15,697' TD = 15,697' MD &TVD LJ 20" H-40 94 ppf Top Bottom MD 0' 280' TVD 0' 280' Cmt/w 525 sacks Surface Casing 13-3/8" N-80 & J-55 74 ppf Top Bottom MD 0' 2,211' TVD 0' 2,211' Cmt/w 2,000 sacks Intermediate 40 ppf 9-5/8" N-80 & S-95 43.5 ppf 47 ppf Top Bottom MD 0' 8,835' TVD 0' 8,835' Cmt w/ 1,370 sacks Production Liner 29 ppf 7" N-80 & P-110 32 ppf Top Bottom MD 5,268 15,439' TVD 5,268' 15,439' Cmt w/ 650 sacks Liner 5" N-80 18 ppf FJ Hydrill Top Bottom MD 15,415' 15,697' TVD 15,415' 15,697' Cmt w/ 41 sacks Production Tubing 3-1 /2" N-80 9.2 ppf Otis XA circ sleeve 4,889' Baker FH hyd packer 4,923' Baker WL entry guide 4,961' Well Name & Number: Beaver Creek #2 Class II Disposal Well Lease: Beaver Creek Unit, Pad 2 County or Parish: Kenai Penisula Borough State/Prov.: Alaska Date Completed: RKB: 15' Country: USA Angle/Perfs~ Angle @ KOP and Depth: 0° KOP TVD: Ground level: 140' PrepareC By Kevin Skiba east Revision Cata 3119/2008 BC 2 -Monthly Injection Report PTD#167-026 -November 2008 Page 1 of 1 • • Regg, James B (DOA) From: Dammeyer, Michael D. [mddammeyer@marathonoil.comJ Sent: Monday, December 01, 2008 3:59 PM ~~ r z ~z+~ To: Regg, James B (DOA) '"` Cc: Ibele, Lyndon; Dammeyer, Michael D.; Miranda, Kyle; Walsh, Ken Subject: BC 2 -Monthly Injection Report PTD#167-026 -November 2008 Attachments: BC2 Nov 2008 Injection Summary PTD167026.ZIP BC 2 -Injection Summary PTD167-026 -November 2008 -Marathon Oil Company Enclosed is the Beaver Creek 2 Injection Summary PTD167-026 for November 2008, submitted monthly via email. Quick Summary: Everything remains within the guidelines, that is: 1) The Inner Annulus Pressure has remained below 1000 psig. 2) No communication to the Outer Annulus has been realized. ~ 3) No OA or IA pressure bleeds were performed. ~ Any questions or concerns, please do not hesitate to call or email. Marathon Oil Company Michael Dammeyer Production Engineer II 907-283-1333 Items included in the BC 2 report for November 2008: 1. Flowrate (BPD) 2. Inner Annulus Pressure (psig) (must stay below 1000 psig) 3. Outer Annulus Pressure (psig) (must notify the AOGCC if any communication is realized) 4. Tubing Pressure (psig) 5. Volume Injected (BPD) 6. All OA and lA Pressure Bleeds «BC2 Nov 2008 Injection Summary PTD167026.ZIP» 12/2/2008 ,9 °o ion M N I r--r .~ o~ a~ m ~, m ~' E~ ~rn o ~ . >~ a~ a~ U~ .~,Q c ~ I ^1 ca E c :rn Q, o ~~y ~" ~ ~~ G~ ~ ~ ~~ 00 ~ ~ c~ o QQ o ` N ~ ~ O ~c Z ~- N • • m ' w m .~ Q .~ c ~ o,Q m ~~, ~-Qm ~~--~. c~ ~ 3~~ ~ ~O ~~~ ^•~ • (6isd) a~nssa~d 00 ~°n o ~°n °o ~°r~ °o ~ N O 1~ ~ N O N N N ~ ~ ~ ~ ^ ~ ^ ^ ^ ^^ ^r ^~^^~ ~• ^1 ~i ^ • • ^~ ~ M ON O ~ OHO N ~ ~ r r r r (ad8) awn~on pue a;e~nno~~ °a °o on I~ ~ N O _~ 0 0 M N - ---- 12/1 /2008 ~ ~ 11 /30/2008 11 /29/2008 11 /28/2008 I I 11 /27/2008 ~ 11 /26/2008 11 /25/2008 `~~ 11 /24/2008 ~ 11 /23/2008 • ! 11 /22/2008 • 11 /21 /2008 11 /20/2008 ! ~ 11 /19/2008 ^!. 11 /18/2008 ~ 11 /17/2008 ^ 11 /16/2008 E ^': 11/15/2008 ~ I 11 /14/2008 ^ 11 /13/2008 ^ 11/12/2008 '^ 11/11/2008 ^ ~ 11 /10/2008 1 • 11 /9/2008 ~ 11 /8/2008 !^ 11 /7/2008 ~! 11 /6/2008 ` ^ 11 /5/2008 ~ ' 11 /4/2008 ^ 11 /3/2008 '' 11 /2/2008 ^ ' 11 /1 /2008 10/31 /2008 0 N r 0 ,~L~~:u,:~i- Z.~v ~C - z- Inner Annulus Pressure Bleeds Date Time Pressure (before) Pressure (after) None None .None None Outer Annulus Pressure Bleeds Date Time Pressure before) Pressure (after None None None None BC 2 -Monthly Injection Report PTD#167-026 -October 2008 Regg, James B (DOA) From: Dammeyer, Michael D. [mddammeyer@marathonoil.com] ~7 ~~~ Sent: Monday, November 03, 2008 12:13 PM To: Regg, James B (DOA) Cc: Ibele, Lyndon; Dammeyer, Michael D.; Miranda, Kyle Subject: BC 2 -Monthly Injection Report PTD#167-026 -October 2008 Attachments: BC2 Oct 2008 Injection Summary PTD167026.ZIP BC 2 -Injection Summary PTD167-026 -October 2008 -Marathon Oil Com~anv Page 1 of 1 I I ~ ~~~~ Enclosed is the Beaver Creek 2 Injection Summary PTD167-026 for October 2008, submitted monthly via email. Quick Summary: Everything remains within the agreed guidelines, that is: 1) The Inner Annulus Pressure has remained below 1000 psig. 2) No communication to the Outer Annulus has been realized. 3) No OA or IA pressure bleeds were performed. Any questions or concerns, please do not hesitate to call or email. Marathon Oil Company Michael Dammeyer Production Engineer II 907-283-1333 ~~,~, ggi~nn .~ f ~~~ Items included in the BC 2 report for October 2008: 1. Flowrate (BPD) 2. Inner Annulus Pressure (psig) (must stay below 1000 psig) 3. Outer Annulus Pressure (psig) (must notify the AOGCC if any communication is realized) 4. Tubing Pressure (psig) 5. Volume Injected (BPD) 6. All OA and lA Pressure Bleeds «BC2 Oct 2008 Injection Summary PTD167026.ZIP» 11 /3/2008 .,2- ~r~ 2e~~~ Inner Annulus Pressure Bleeds Date Time Pressure (before) Pressure (after) None None None None Outer Annulus Pressure Bleeds Date Time Pressure (before Pressure after) None None None None N C~ E E 0 m ._ 00 o~ c~ ~i r O N U m (6isd) amssa~d °o ~°n °o ~°n °o °n °o°r~ o O I~ to N O f~ l(') N O M N N N N ~ r- ~ ~ ~ • ~~ ^~ rn .~ w - ^ a m ~ ', :~r~ ^ r • ^ ~~ ^ a~ a~ a ~^ ~ rn ; • ~Ir ~•~ f ~~ ~ ~ ~ i i I "~ c ~. ^+ ~ .r ~ ^ ^~ ~^ ~ 1~1P~j ~ Q~ .~g ~N ~~ ~~ c~ c~ QQ `` m ~c 05 • • rn .N Q c M~ W ~~ L ~/ ~ ~c ~ ~ 3~~ ~ ~O ~~~ ^•+ ~^ ^~ i~ ', ^ ~ f ~~ ^ ^~ ^ °n I~ °o ion ~ N 1 i I ~ i i~ ^ • ^' ',• '^ ^. ^ r r ^ ^' ^ ^ ~y I ••w. 1 I Ir__ 0 0 0 0 0 0 0 0 0 0 0 0 ~ N O 00 (O ~ N O DO CO ~?' N ~ M N O O O ti O ~ M N ~ r r r r (ddb) awn~on pue a;e~nno~~ --~ 11 /1 /2008 10/31 /2008 10/30/2008 10/29/2008 10/28/2008 10/27/2008 10/26/2008 10/25/2008 10/24/2008 10/23/2008 10/22/2008 10/21 /2008 10/20/2008 10/19/2008 10/18/2008 10/17/2008 ~ 10/16/2008 ~ 10/15/2008 10/14/2008 ` 10/13/2008 10/12/2008 10/11 /2008 ' 10/10/2008 10/9/2008 10/8/2008 10/7/2008 10/6/2008 10/5/2008 10/4/2008 10/3/2008 10/2/2008 10/1 /2008 0 M Marathon MARATHON Oil Company ~~~f~~~~~ ~~lr ~ ~` ~~~~ October 7, 2008 Mr. Tom Maunder Alaska Oil & Gas Conservation Commission 333 W 7th Ave Anchorage, Alaska 99501 Reference: 10-404 Report of Sundry Well Operations Field: Beaver Creek Field Well: Beaver Creek #2 Dear Mr. Maunder: Marathon Oil Company Alaska Asset Team P.O. Box 1949 Kenai, AK 99611 Telephone 907/283-1371 Fax 907/283-1350 RECEIVEt~ O C T 0 9 [i~D Alaska Oil & Gas Cons, Cgs-r,r„ission Anchorage l6~ Attached for your records is the Report of Sundry Well Operations 10-404 for BC-2 well. This sundry covers the acid stimulation work performed under Sundry #308-283. A blend of Xylene, HCL, & Ammonium Chloride was pumped into the Sterling formation in stages. This resulted in an injection pump-in tubing pressure reduction of approximate 100 psi. Please contact me at (907) 283 -1371 if you have any questions or need additional information. Sincerely, -~~.~-g. s~- Kevin J. Skiba Engineering Technician Enclosures: 10-404 Report of Sundry Well Operations cc: Houston Well File Operations Summary Kenai Well File KJS ~~ STATE OF ALASKA /O ~~-Ott ALA~OIL AND GAS CONSERVATION COMIv~ON REPORT OF SUNDRY WELL OPERATIONS AI R~~~'~ ^~ o ~ loas 1. Operations Abandon Repair Well Plug Perforations Stimulate ~ r S CQ(~S ~ . Al11f~tSSit3 Performed: Alter Casing ^ Pull Tubing ^ Perforate New Pool ^ Waiver ^ Time Extensio ~ ~ ~~~`~~~ Change Approved Program ^ Operat. Shutdown ^ Perforate ^ Re-enter Suspended Well 2. Operator Marathon Oil Company N 4. Well Class Before Work ' ~ 5. Permit to Drill Number: ame: Exploratory Development [~ 167-026 - 3. Address: p0 BOx 1949 Stratigraphic ^ Servic 6. API Number: Kenai Alaska, 99611-1949 ~~ 50-133-20021-00-00 - 7. KB Elevation (ft): 9. Well Name and Number: 155' KB (15' AGL) - Beaver Creek #2 8. Property Designation: 10. Field/Pool(s): _ FED A-028118 Beaver Creek Field /Sterling Formation 11. Present Well Condition Summary: Total Depth measured 15,697' ~ feet Plugs (measured) 5,197' true vertical 15,697' - feet Junk (measured) NA Effective Depth measured 5,197' feet true vertical 5,197' feet Casing Length Size MD TVD Burst Collapse Structural Conductor 265' 20" 280' 280' NA NA Surface 2,196' 13-3/8" 2,211' 2,211' 3,450 psi 1,950 psi Intermediate 8,820' 9-5/8" 8,835' 8,835' 6,330 psi 3,610 psi Production 10,171' 7" 15,439' 15,439' 8,160 psi 7,020 psi Liner 2g2' 5" 15,697' 15,697' 10,140 psi 10,490 psi Perforation depth: Measured depth: 5,007' - 5,220' True Vertical depth: 5,007' - 5,220' Tubing: (size, grade, and MD) 3-1/2" N-80 4,961' Packers and SSSV (type and measured depth) Baker FH Packer 4,923' 12. Stimulation or cement squeeze summary: Intervals treated (measured): Marathon performed a Mud Acid Stimulation on BC-2 well. A blend of Xylene, HCL, & Ammonium Chloride was pumped into the Sterling formation in stages. This resulted in a pump-in tubing Treatment descriptions including volumes used and final pressure: pressure reduction of approximate 100 psi. 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 0 596 0 (outer) 2,379 psi Subsequent to operation: 0 0 582 0 (outer) 2,274 psi 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run Exploratory ^ Development ^ Service ^~ Daily Report of Well Operations X 16. Well Status after work: Oil ^ Gas ^ WAG ^ GINJ ^ WINJ ^ WDSPL ^~ - 17. Thereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 308-283 Contact Kevin Skiba (907) 283-1371 Printed Name Kevin J. Skiba Title Engineering Technician Signature - ~ ~'`,v-'C/ Phone (907) 283-1371 Date October 7, 2008 Form 10-404 Revised 04/200 ~~ ~ ~ ^ I ~ I (~ ~ _.• ~s. ~ ^r Submit Original Only Lam, (~ '= ry~~~ ~ Operations Summary Report ,,,~~, -~~tComp~y Well Name: BEAVER CREEK 02 Re ort Date: 9/102008 Job Cate o R&M MAINTENANCE 24 Hr Summary MIRU BJ acid equipment and materials. Ops Trouble Start Time End Time Dur hrs O s Code Activi Code Status Code Comment 11:00 12:00 1.00 SAFETY MTG AF Hold PJSM. Discuss alarms, muster area, and emergency response. Discuss BJ JSA, MSDS for chemicals and specific job hazards. Obtain SWP. 12:00 13:00 1.00 RURD EOIP AF Lay liner and drip pans. Spot HF acid trailer and off load to poly tank. 13:00 15:00 2.00 RURD EOIP AF Spot xylene trailer and daisy chain tanks together. Spot pump van. RU suction side of van. RU discharge side of van. Finish berming chemical storage area. 15:00 16:00 1.00 SECURE WELL AF Secure all tanks and equipment on location. All acid tanks valves closed, all hose ends capped. Did not RU to WH yet. Turn in permit and sign out. Re ort Date: 9,'11;2 008 Job Cate o R&M MAINTENANC E 24 Hr Summary MIRU BJ acid equipment and materials. Pump 1500 gals Xylene, 3000 gals 7.5% HCL, 4% HCL11 % HF acid Ops Trouble Start Time End Time Dur hrs O s Coda Activi Code Status Code Comment 08:00 08:45 0.75 SAFETY MTG AF Hold PJSM. Discuss alarms, muster area, and emergency response. Discuss BJ JSA, MSDS for chemicals and specific job hazards. Obtain SWP. 08:45 10:30 1.76 RURD EQIP AF Spot 7-1l2 %HCL trailer and daisy chain tanks together. Add 3% Ammonium Chloride and 1 gal/M Inflo to 25 bbls fresh water. Add 1 gal !M to 50 bbls produced water. Spot vac trucks. RU discharge side of van. Close swab valve and RU 2" hard line to WH. Finish berming chemical storage area. 10:30 11:00 0.50 RURD EQIP AF Flood suction hoses w/ water. Check for Ieaks.Leak in van on suction. Shut down repair flapper valve. 11:00 11:09 0.15 TEST EQIP AF Open swab valve. WHP 2060 psi. Annulus P 400 psi. Pump 1 bbl. Close swab valve and PTest to 4000 psi. Test good. 11:09 12:30 1.36 PUMP ACID AF 11:15 Pumping Xylene @ 1!2 bpm 2100 psi. (1500 gallon Stage) 11:32 7.1 bbls pumped @ 1/2 bpm 2290 psi 11:45 14.1 bbls pumped @ 1l2 bpm 2470 psi 12:00 21.2 bbls pumped @ 1r2 bpm 2490 psi 12:15 28.5 bbls pumped @ 1I2 bpm 2550 psi 12.30 35.8 bbls Xylene pumped www.peloton.com Report Printed: 10!12008 ,- M~~ ~ Operations Summary Report ,,,,~ TQj~ Y Well Name: BEAVER CREEK 02 Start Time End Time Dur hrs 0 s Code Aetivi Code Ops Status Trouble Coda Comment 12:30 14:39 2.15 PUMP ACID AF Shut down 15 minutes and allow xylene to soak. 12:45 Start pumping One Shot (7-112% HCL) @ 112 bpm 2590 psi. (3000 gallon stage) 13:00 3-112 bbls HCL pumped @ .5 bpm 2665 psi. Annulus 400 psi. 13:22 16 bbls HCL pumped @ .65 bpm 2620 psi. 13:35 25 bbls HCL pumped @ .65 bpm 2575 psi. 13:45 30 bbls HCL pumped @ .65 bpm 2570 psi. Shut down for 20 minutes to soak xylene. 14:05 Resume pumping HCL@ 2 bpm 2590 psi. 14:10 40 bbls HCL pumped @ 2 bpm 2660 psi. 14:18 50 bbls HCL pumped @ 1 bpm 2540 psi. Acid on formation. 14:22 60 bbls HCL pumped @ 1 bpm 2540 psi. 14:35 70 bbls HCL pumped @ 2 bpm 2700 psi. HCL pumped complete. 14:39 15:21 0.70 PUMP ACID 14:35 Start pumping HF acid.@ 2 bpm 2790 psi. (3000 gallon stage) 14:40 10 bbls HF acid pumped @ 2 bpm 2780 psi. 15:00 38 bbls HF acid pumped @ 2 bpm 2705 psi 15:05 45 bbls HF acid pumped @ 2 bpm 2650 psi. 15:07 5D bbls HF acid pumped @ 2 bpm 2640 psi. Acid on formation. 15:12 60 bbls HF acid pumped 15:16 68 bbls HF acid pumped@ 2 bpm 2640 psi. HF acid complete. 15:21 15:39 0.3i~ PUMP WTR AF 15:21 Start pumping 3% Ammonium chloride water@ 2 bpm 2520 psi. [750 gallon stage) 15:34 15 bbls Ammonium chloride pumped @ 2 bpm 2550 psi. Annulus P 400 psi. 15:40 25 bbls Ammonium chloride pumped @ 2 bpm 2570 psi. Stage complete. 15:39 16:09 0.50 PUMP WfR AF 16:00 Start pumping produce water flush @ 2 bpm 2520 psi. (1800 gallon stage) 16:10 20 bbls pumping produced water @ 2.1 bpm 2620 psi. 16:30 40 bbls pumping produced water@ 2.1 bpm 2720 psi. 16:40 60 bbls pumped produced water stage complete. Shut down. 16:42 2508 psi 16:44 2473 psi 16:46 2432 psi 16:09 17:45 1.60 KURD EQIP RD equipment. Flood chemical lines w1 fresh water. uac out w/vac truck. RD suction side of pump van. Vac out discharge pumps and hard lines. RD 2" hard lines. Reinstall tree cap and instrument line. Pressure test to 2000 psi. Test good. No leaks. 17:45 18:03 U 30 SECURE WELL Secure well head and location. Return well to operations. Turn in permit and sign out. www.peloton.com Report Printed: 10!112008 BC 2 -Monthly Injection Report PTD#167-026 -September 2008 • Regg, James B (DOA) From: Dammeyer, Michael D. [mddammeyer@marathonoil.com] Sent: Wednesday, October 01, 2008 11:40 AM To: Regg, James B (DOA) Cc: Ibele, Lyndon; Walsh, Ken; Henry, Nancy J.; Miranda, Kyle Subject: BC 2 -Monthly Injection Report PTD#167-026 -September 2008 Attachments: BC2 Sep 2008 Injection Summary PTD167026.ZIP Page 1 of 1 l IS ~~~" ~~ Enclosed: BC2 Sep 2008 Injection Summary PTD167-026 Marathon Oil Company Michael Dammeyer Production Engineer II 907-283-1333 «BC2 Sep 2008 Injection Summary PTD167026.ZIP» 10/ 1 /2008 ~~,_z ~~~~ z Inner Annulus Pressure Bleeds Date Time Pressure (before) Pressure (after) None None None None Outer Annulus Pressure Bleeds Date Time Pressure before) Pressure after None None None None • • ~~ -~ C~' e~ E m ._ 00 0 0 N a m N m (6isd) aanssa~d °o ° °o ~°n °o ~°n °o ~°n °o 0 0 0 O M I~ ~ N N N O ti N N ~ ~ N ~ ~- O In ~-- I~ O lf') ~ N O -- - ~ ~M -~ ~ r,- A - ~ ~ ,-~----~ - - r 10/1 /2008 ~ ~ ~ 9/30/2008 ~ .-. rn ~ ~ • ^ ~ ~ 9/29/2008 n ~ ~~ ~ ' I ~~~ ^ ~ 9/28/2008 a~ ~ m ~ ^~ ^ 9/27/2008 mom' ' a ~ , ~ ~ ~ i ~ 9/26/2008 ~ ~ ~ ~ ~ ' ~ ~rn o ~ i ~ i~r ~ ~ ' • 9/25/2008 ~ ~ ~ ~+ ' I ! ^ ~ 9/24/2008 .~ p c ~, ~ r ~ • ~ I I ~ '. 9/23/2008 i ~ 9/22/2008 ~ MI-~ ^ ~ ~^~ ^ ~ 9/21 /2008 ~ ~ i • ^ ~ 9/20/2008 • ~ ^ ^~ ~^ ' ~ I ^ ~ 9/19/2008 ~ ... ~ ^ ^~ ~ ~ - 9/18/2008 Q Q ' i^ ^~^ I ~ ! ^ 9/ 17/2008 ~ 9/16/2008 ~ ~ ~ ^~ ~ c ""' ~ ~~ ~ ^. 9/15/2008 L L ~ m ~ ' ~ ,~^^~ ~ j^ ~ ' 9/14/2008 I O ~ ~ ~ '~''! ~ ~ ^ I ' ~ ^ ! 9/13/2008 * • i I^ - 9/12/2008 ~ ' ~ ^ 9/11 /2008 rn ~ i ; •~ i ' ^ ~ 9/10/2008 , ~ , ^ ~, i rte! ^ ~ • 9/9/2008 ~ c ~ , M r ^r •^ i~ ~ i ~ ~ ~ ! ! 9/8/2008 l . ~ ~ ~ ~ ~ i I^ ' 9/7/2008 ~ ~,¢ m I , n c ~ '~ ^~ • 9/6/2008 3: ~ Q ~ ~ Mi~~' .~ ~Y~i~. ' ~1 r^ ~ ^ { 9/5/2008 o ~ O ~~~ ; ~ ~~ ~ '~ ^ ~ ~ ^ ~ { 9/4/2008 ^ . + M ', I, ^ 9/3/2008 ~ ~! ~~ ~ ^ ^ ~ , ~ ~ i ~~ ! ~ ^ ~ 9/2/2008 ~ rte ~ --- - - --- 8 .. - --- -- - 9/1 /200 0 ~ 0 0 N O 0 0 0 oO (p ~ 0 0 N O 0 0 00 CO 0 0 ~ N 0 ~ ~ M N r r O O O r ti O V M N ~ (ad8) awn~on pue a;e~nno~~ Beaver Creek #2: PTD #167-026 and 403 Sundry Approval #308-2$3 Page 1 of 2 • Maunder, Thomas E (DOA) Frorn: Maunder, Thomas E (DOA) Sent: Monday, September 08, 2008 2:48 PM To: 'Walsh, Ken' Cc: Cisseil, Wayne E.; Dammeyer, Michael D.; Ibele, Lyndon; Miranda, Kyle; Mullin, Mickey; Rang, Craig L.; Skiba, Kevin J.; Sulley, Michael Subject: RE: Beaver Creek #2: PTD #167-026 and 403 Sundry Approval #308-283 Ken, You are correct of my message to Kevin. With regard to your question, the sundry approval relates to the operation "stimulate". In trying to keep the well files as accurate as possible, I believe that having the design as part of the file is important especially since this is a Class II disposal well. Good luck with the operation. Call or message with any questions. Tom Maunder, PE AOGCC From: Walsh, Ken [mailto:kdwalsh@marathonoil.com] Sent: Monday, September 08, 2008 2:36 PM To: Maunder, Thomas E (DOA) Cc: Cissell, Wayne E.; Dammeyer, Michael D.; Ibete, Lyndon; Miranda, Kyle; Mullin, Mickey; Rang, Craig L.; Skiba, Kevin J.; Sulley, Michael Subject; Beaver Creek #2; PTD #167-026 and 403 Sundry Approval #308-283 Tom, As you are aware, Kevin Skiba with Marathon Oil Company contacted you this morning by telephone to discuss whether a recipe change to the acid stimulation planned and approved for the BC #2 water injector required additional approval. You said that no additional approval was necessary but asked that we send an email to you outlining the new acid treatment schedule that we intend to pump. The new schedule is as follows: Pump in the following order: 1. 1500 gals Xylene 2. 3000 gals One Shot (75% HCL - 25% Xylene) 3. 3000 gals Mud Acid (4% HCL - 1% HF acid) 4. 750 gals 3% Ammonium Chloride 5. 1812 gals 2% KCL or formation brine. I hope this meets your needs. As a matter of clarification, does the AOGCC approval Dover the fact that the interval is being stimulated or does it cover the design, too. .7leic Ken D. Walsh Senior Production Engineer Marathon Oil Company-Alaska Asset Team 907.283-1311 {office) 9/8/2008 BC 2 -Monthly Injection Report PTD#167-026 -August 2008 • Page 1 of l Regg, James B (DOA) ~ ~ ~ ~- ~ ~ From: Dammeyer, Michael D. [mddammeyer@marathonoil.comj Sent: Wednesday, September 03, 2008 6:15 AM To: Regg, James B (DOA) Cc: Ibele, Lyndon; Dammeyer, Michael D. Subject: BC 2 -Monthly Injection Report PTD#167-026 -August 2008 Attachments: BC2 Aug 2008 Injection Summary PTD167026.ZIP Enclosed: BC2 Aug 2008 Injection Summary PTD167-026 Marathon Oil Company Michael Dammeyer Production Engineer II 907-283-1333 «BC2 Aug 2008 Injection Summary PTD167026.ZIP» 9/3/2008 • `~`^~~ ~O Inner Annulus Pressure Bleeds Date Time Pressure (before) Pressure (after) Outer Annulus Pressure Bleeds Date Time Pressure (before) Pressure (after) None None None None ~a~ t~ 1 ti • • (6isd) a~nssa~d °o °n °o -°n °o ~°n °o ~°n o 0 0 0 O I~ ~ N O ~ In N O ~ O ~ M N N N N ~ ~ ~ r' ti ~ N O -----..w••- - _ - f _ 8/31/2008 •.~ ~ ^~ • ~ 8/30/2008 ., - ~ • r~ I 8/29/2008 .rn ! ~~ ^~ n v 8/28/2008 a~ a ~ I ;, •~ ~ 8/27/2008 ~ ~ ' ', 8/26/2008 a o ~ f ! "'~' _ i 8/25/2008 ~ ~ ~~ ~ ^ ~ 8/24/2008 ~ ' 'i ~ ~ ~ 8/23/2008 ~~ 5 ~ 8/22/2008 ~ 8/21 /2008 «i.•~ ! ~. ~' ..~.~~ ~ . • 8/20/2008 ~ ~ --~~~ ~ ~ 8/19/2008 N ' ^* ~ 8/18/2008 ~ °'~ ~ ~ 8/17/2008 o ~ ~~, I ~ ~~ i ~r ~ ' 8/16/2008 ~ •4; ~ ~ ~ ~ ~ ~ ~ ' ~~ ~ 8/15/2008 ~- 00 ~ ~ I °o Q Q ~ ^ ~ 8/14/2008 .~ a~ ~ O ~ ~ i 8/13/2008 -~ • N ~ ~ i ~ 8/12/2008 V 8/11 /2008 00 8/10/2008 rn ', 8/9/2008 ~~ °' ' ~ 8/8/2008 ~ j 8/7/2008 pa ^Q .r. • ^^~ M ~ ; ~ 8/s/2oo8 W ~ ~ L i .I ~ ~ c ~r a ', ~ 8/5/2008 c~a o~ o ~ o ti i r ~ 8/4/2008 u. ~ H ! M•~ ~ ~ 8/3/2008 j ~, I 8/2/2008 i ~~~' ~ -- ' ./~ 8/1 /2oo8 i 7/31 /2008 0 0 0 0 0 0 0 0 0 0 0 0 0 ~ N O 00 Cfl ~ N O 00 (fl ~ N ~ M N O O O ~ CO '~ M N ~ ~ ~ ~ ~ (ad8) awn~on pue a~e~nno~~ ~ ~ ~~ ~ ~ ~ ~ ~ ~~ t ~ r i f ~~ ~r~~ i t ~ COI~TSERQ~ AT'IprT C01- IISSIpIS~T Wayne Cissell Well Work Over Supervisor Marathon Oil Company PO Box 1949 Kenai, AK 996 1 1-1 949 • SARAH PAL1N, GOVERNOR 333 W. 7th AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PMONE (907) 279-1433 FAX (907) 276-7542 ~b~.o~ ~~ Re: Beaver Creek Field, Undefined Waste Disposal Pool, Beaver Creek #2 Sundry Number: 308-283 Dear Mr. Cissell: Sr~n~l ~U~ ~, ~~ 2008 Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing, A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, Daniel T. Seamount, Jr. Chair DATED B 3 this -day of August, 2008 Encl. C M Marathon MARATHON ail Company August 7, 2008 Tom Maunder Alaska Oil & Gas Conservation Commission 333 West 7'" Ave, Suite 100 Anchorage, AK 99501 • Marathon_(,~il Company Alaska Asset beam P,O. Box 9949 Kenai, AK 99~'~ 1 Telephone (9~U~f)~Y8~-1~~37;'1~_ Fax (907) 283-1350 Reference: 10-403 Sundry Application Field: Beaver Creek Production Facility Well: BC #2 Dear Mr. Maunder Enclosed please find the request for your approval to mud acid treat the Beaver Creek water injection well at Beaver Creek. The well has been experiencing high injection pressures over the past month. A form 10-403 and the associated attachments are included. Attachments include a well bore schematic, proposed well bore schematic, 10-403 Sundry form, and work scope procedure. Should you require further information, I can be reached at 907-283-1308 or by a-mail at wecissell@MarathonOil.com. Sincerely, Wayne Cissell Work Over Supervisor Enclosures: 10-403 Sundry Well bore schematic Procedure Summary MARATHON Marathon Oil Company Alaska Region Beaver Creek #2 Water Disposal Well Beaver Creek Field, Pad 2 Mud Acid Cleanout WBS # ??? • History: Produced water from BC field is injected into Sterling B-l, B-2, and B-3 benches. Injection pressure has increased 250 psi (from 2250 to 2600) during August 2008 with an average daily injection volume of 400 BWIPD. The wellbore is constructed with 3 '/2", 9.2 ppf tubing in 9-5/8" casing. The tubing tail is at 4961' and minimum ID is 2.75". There is an Otis XL Ball Valve Nipple at 483' KB and an Otis XA Circ Sleeve at 4889'. 'The difference between GL and KB is 15'. Objective: Acidize the Sterling B1 through B3 perforations with mud acid to reduce wellhead injection pressure. Procedure: 1. Spot liner on location as needed. Lay Liner and berm under BJ Services acid transport and pump lines. Call out vac truck to supply filtered produced water to BJ Services pump to pressure test BJ Services pump lines and displace acid treatment down the production tubing. 2. MIRU BJ Services acid transport and enclosed fluid pump. NOTE: Tree flange connection is 4-1/16", lOK. Hold PJSM to discuss potential hazards and operational plan. Review MSDS sheets of all chemicals present and have appropriate PPE donned. Ensure pressurized eye wash container and Calcium Gluconate neutralizing kit for HF acid is on location. MU pump lines ensuring that drip pans are placed under all connections. Record and report annulus pressure, injection rate, and injection pressure prior to beginning pumping operations. 4. Pressure test BJ Services pump lines to 4000 psi with produced water . Maximum surface pressure not to exceed 2900 psi during acidizing operations. ~ Page 2 of 2 5. Commence pumping (bullhead) acid treatment as follows monitoring pressure and rates: a. 1000 gals. 7.5%HCL acid with additives @ 2 BPM b. 800 gals. 6% HCL and 1.5% HF acid with additives @ 2 BPM c. 1200 gals. 6% HCL and 1.5% HF acid with additives @ 1 BPM d. 1000 gals. 7.5%HCL acid with additives @ 1 BPM e. 80 bbls. filtered produced water flush at 1 BPM. 6. RDMO BJ Services acid pumping equipment. Reinitiate produced water injection through BC facilities. Closely monitor rates, volumes, and surface injection pressures. 7. Please call Ken Walsh at 394-3060 or 283-1311 with questions and results. Beaver Creek #2 Sterling Acid Procedure wec - 8/7/2008 6:44:18 AM STATE OF ALASKA s ~ ALA OIL AND GAS CONSERVATION COM~SION ~t ~'lv APPLICATION FOR SUNDRY APPR}J^~~1/\)V,AI„S, 7A A A!~ /IG IAA " ` - ~•ex~~ a ~k.., ~l;t ,-~1 ~~ 1. Type of Request: Abandon ^ Suspend ^ Operational shutdown^ Perforate ^ Waivet ^ F Other ^ Alter casing ^ Repair well ^ Plug Perforations ^ Stimulate ~ Time Extension ^ Change approved program ^ Pull Tubing ^ Perforate New Pool ^ Re-enter Suspended Well ^ 2. Operator Name: Marathon Oil Company 4. Current Well Class: 5. Permit to Drill Number: Development ^ Exploratory ^ 1s7-o2s' 3 A e . ddr ss: pQ gox 1949 Stratigraphic ^ Service ^ 6. API Number: Kenai Alaska, 99611-1949 50-133- 20021 ~ -00-00 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: ^ Spacing Exception Required? Yes ^ No ~ Beaver Creek #2 9. Property Designation: 10. KB Elevation (ft): 11. Field/Pool(s): FEDA028118 ~ 155' KB(15' AGL) Bea ver Creek/Sterling 12. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 15,697' 15,1697' 5,197' 7,890' 5,197' Casing Length Size MD TVD Burst Collapse Structural 265' 20" 280' 280' n/a n/a Conductor Surtace 2,196' 13 3/8" 2,211' 2211' 3450 1950 Intermediate g,820~ 9 5/8" 8,835' 8,815' 6330 3610 Production 10,171' 7" 15,439' 15,439' 8160 7020 Liner 258' 5" 15,697' 15,697' 10140 10490 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 5007-5028'/5032-5052' 5007-5028'/5032-5052' 31/2" N-80 4961' 5125-5140'/5155-5220' 5125-5140'/5155-5220' Packers and SSSV Type: Packers and SSSV MD (ft): Baker FH Packer 4923' 13. Attachments: Description Summary of Proposal ^ 14. Well Class after proposed work: ~~~( - •_ Detailed Operations Program 0 BOP Sketch ^ Exploratory ^ DevHep men t `-- ~- Service ^~ 15. Estimated Date for ~ A ~ 16. Well Status after proposed work: u , 2008 Commencing Operations: Oil ^ Gas ^ Plugged ^ Abandoned ^ 17. Verbal Approval: Date: t;/ ~ WAG ^ GINJ ^ WINJ ^ WDSPL Q ~ Commission Representative: 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Kevin Skiba (907) 283-1371 Printed Name Wayne issell Title Well Work Over Supervisor Signature P ne Date (907) 283-1308 August 7, 2008 COMMISSION USE ONLY _ n Conditions of approval: Notify Commission so that a representative may witness Sundry Number: ~ ,~ x ~+ Plug Integrity ^ BOP Test ^ Mechanical Integrity Test ^ Location Clearance ^ Other: S ~F~ AUG ~ 4 20D8 Subsequent Form Required: i - (~L ~ APPROVED BY Approved by. 'COMMISSIONER THE COMMISS ION Date: ~a~ /~Od' o ~!~~~ "~~~~ "'-""' ~•°""~" 1°~~'Op ~, F ~ ~ ~ ~ / ~ ~ Submit in Duplicate `v 50-133-20021-00-00 ~rtv Des: FEDA - 028118 15' AGL (155' KB Elevation) Date: 7/13/1967 ate: 11 /9/1967 eleased: 09:OOhrs 12/26/1967 Perforations: Sterling B-1: 5,007'-5,028' 5,032'-5,052' Sterling B-2: 5,125'-5,140' Sterling B-3: 5,155'-5,220' Isolated Perforati ons: Sterling B-3a: 5,230'-5,244' squeezed B-3a: 5,263'-5,265' Sterling B-4: 5,324'-5,344' BV"~ Pad 2 (Infection Well) 590' FNL, 1,979' FEL Sec. 3, T6N, R10W, S.M. ~ c ~ ~ ~ ~ ~ c ~ Fill @ y ~~ t 5,132' SLM (11/11101) ~` Cement Cap @ 5,197 ~ C Cement Retainer @ 5,221' ~ ~ C ~" C ' 7' Liner stub ., @ 5,268' ~ ~ ti R ' 7" liner shoe ~ @ 15,439' 5" liner shoe @ 15,697' TD = 15,697' MD &TVD w Conductor 20" H-40 94 ppf ToD Bottom MD 0' 280' TVD 0' 280' Cmt/w 525 sacks Surface Casing 13-3/8" N-80 & J-55 74 ppf Top Bottom MD 0' 2,211' TVD 0' 2,211' Cmt/w 2,000 sacks Intermediate 40 ppf 9-5/8" N-80 8~ S-95 43.5 ppf 47 ppf Top Bottom MD 0' 8,835' TVD 0' 8,835' Cmt w/ 1,370 sacks Production Liner 29 ppf 7" N-80 & P-1 10 32 ppf ToD Bottom MD 5,268 15,439' TVD 5,268' 15,439' Cmt w/ 650 sacks Liner 5" N-80 18 ppf FJ Hydrill Top Bottom MD 15,415' 15,697' TVD 15,415' 15,697' Cmt w/ 41 sacks Production Tubing 3-1/2" N-80 9.2 ppf Otis XA circ sleeve 4,889' Baker FH hyd packer 4,923' Baker WL entry guide 4,961' Well Name 8 Number: Beaver Creek #2 Class II Disposal Well Lease: Beaver Creek Unit, Pad 2 County or Parish: Kenai Penisula Borough State/Prov.: Alaska Date Completed: RKB: 15' Country: USA Angle/Perfs: Angle @ KOP and Depth: 0° KOP TVD: Ground level: 140' Prepared By: Kevin Skiba Last Revision Date: 3/19/2008 BC 2 -Monthly Injection Rej~PTD#167-026 -July 2008 • Page 1 of 1 Regg, James B (DOA) From: Dammeyer, Michael D. [mddammeyer@MarathonOil.com] Sent: Monday, August 11, 2008 4:01 PM To: Regg, James B (DOA) Cc: Ibele, Lyndon; Dammeyer, Michael D. Subject: BC 2 -Monthly Injection Report PTD#167-026 -July 2008 Attachments: BC2 July 2008 Injection Summary PTD167026.ZIP Enclosed: BC2 July 2008 Injection Summary PTD167-026 Marathon Oil Company Michael Dammeyer 907-283-1356 «BC2 July 2008 Injection Summary PTD167026.ZIP» „~° A U G ~ ~ ~~~~ 8/19/2008 (]~ ~~ ~r Vy c 0 m_ a~ a >~ a m U ._ '1 n •_ ~ ~ o ~ o Q N L N ~+ }' ~ O N ~• m 0 a m• 0 ^• • (6isd) a~nssaad • o°°n °o °n °o°r~ °o °n °o 0 0 0 O I~ ~ N O f~ ~ N O ~ O ~ M N N N N ~ ~ ~ ~ f~ ~ N O -~--- - - _ - ----- 8/1 /2008 ~~~~ ~ ~ 7/31 /2008 a, ~ 7/30/2008 `- ~ ~ 7/29/2008 a~ '~ ~ i ~~~ ~ ~~ ( 7/28/2008 cn I ~ • ~ ~' ~' '~ 7/27/2008 a' Imo' ~'~~~I ~ ~ I 7/26/2008 ~ 'I ~~~ ~ 7/25/2008 --O ! 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" ^ r ~ ' M.•• ~ ~ 7/14/2008 ~ ~ ~~ ~ ~ ~ wl~j• + ~ ~ 7/13/2008 i ! ~Mj11 ~ ~ 7/12/2008 I', «~~ ; ~ ~ i 7/11 /2008 ~~ ~~. ~ ~; 7/1 o/loos •(p ~ ' r~~•• ~__,~~,~~- ~i~ ' ~' ~ .~, ~ •,r"'*~- ^ ~ ~' ~ 7/9/2008 ~ * ~ ~ ~ ~ i ~ 7/8/2008 c o,Q ~ ~ ~' 7/7/2008 ~~ i ~ ~ ', ~ ~ i, 7/6/2008 ~ ~ ', ~ ~ ~ i 7/5/2008 ~ ~ ~ ~ r ~ 7/4/2008 l , ~r-.~ , •••~ ~ T ..~.• ~ • r , 7/3/2008 - ~, ~ 7/2/2008 - 1 ' --i--~ ----- - ~ --~! - 7/1/2008 0 0 0 0 0 0 0 0 0 0 0 0 0 ~ N O 00 C~ ~ N O 00 CO ~ N '~' M N O O O ~ CO ~ M N ~ r r r r ~dd8) aum~on pue a~e~nno~~ i ~ ~ gc - z Inner Annulus Pressure Bleeds Date Time Pressure (before) Pressure (after) 7/4/2008 1:30 440 330 Outer Annulus Pressure Bleeds Date Time Pressure (before) Pressure (after) None None None None BC2 June 2008 Injection Summary PTD167026.x1s Page 1 of 1 Regg, James B (DOA) From: Donovan Jr, Dennis M. [ddonovan@marathonoil.com] Sent: Wednesday, July 09, 2008 7:45 AM `t~ To: Regg, James B (DOA) /~~~ ~ Z(~~~~ Cc: Skiba, Kevin J.; Ibele, Lyndon; Donovan Jr, Dennis M. Subject: BC2 June 2008 Injection Summary PTD167026.x1s Attachments: BC2 June 2008 Injection Summary PTD167026.ZIP Jim, Attached is the June 2008 BC#2 injection summary. There is some data from June 1st thru June 12th that is TOW data due to our SCADA constant monitoring system intermittently not working. Thanks Dennis «BC2 June 2008 Injection Summary PTD167026.ZIP» V ~)C~tl~~ ~~~L~ ~'^~S c~s~~ ScA~~ ~~~~,~ ~~ JUL ~ ~ 200$ 7il si2oos ~ ~~ >> ti (6isd) aanssa~d ~ 0 o 0 0 ~n o 0 0 0 ~n o ~n 0 0 o ~n 0 o 0 0 0 ' ~- O M f~ l!') N N N O I~ N N ~ ~ N ~ ~ O ~ ~ O LL ) f~ ~ N O r ~-.`r •, w~ n. - _ _ _~ - 7/1 /2008 ` M • • ~~ ~ ^ 6/30/2008 ~ 6/29/2008 n ~ • s ~ ^ o ~' ~ ~,.• ~ 6/28/2008 m N I ~ .•;• f ' ^ ~ ~ ! ~• • y ~ 6/27/2008 a ~ rn I •'~' '~ ~ ' i ^ I 6/26/2008 o c ', ~ ~ • ', ^ ~ ~ ~,. ~ • ! 6/25/2008 ~' .moo ~" • • .~•• r r ~ ^ ! ~ ^ 6/24/2008 ~ ~ .• • r ~ 6/23/2008 6/22/2008 ~• ~ ~ I ^ +~+ • ~ ! ~ ~ 6/21 /2008 ~ ~r i I ^ ~ _ rrr~ r ' - ~ 6/20/2008 ~ r ~,,wm ~ , ^ ~ ~ ~! ..w- '• ' ! ~ I 6/19/2008 cn «rv, ~ ^ ~ I ^ c ~, ~ ', ..w~~ r ~ ^ 6/18/2008 }, Q~~ n ~ 'r'•~ ~ i i 6/17/2008 '_ ~ ~ ' i ~ ' ~ 6/16/2008 ~ I ° Q ' 6/15/2008 o Q ' ^~ M ^ d ~ u`, ~ ! ~ j ~ 6/14/2008 ~ ~ ! 6/13/2008 ~ N ~ • ' I ' * ; ' ~ ^ ~ ~^ 6/12/2008 U m o ~ ,, I ~^ ~ ! ~ ~ ` ~ rr 6/11 /2008 I ^ 3 Q Q ~ ', 6/10/2008 °' EU- }' ~ ~ ~ ~ c • ' I ~ 6/9/2008 ~ ~ ~~c~ N ~ ' i ~ ^ ~' ' ~ ~ 6/8/2008 ~ ~ o„ ' ~ ^ ~ .o ~ a , I ~' ~ j sn/loos ~ rnQ ~. o'. ~ ~ , i ~ 6/6/2008 °° ~~, ~ ~, zs ~ j ~ ^ j~: ^ ~ °" ~ c'' ~ ~ '' I,I ~ ~ '~, ~ 6/5/2008 0 o 6/4/2008 ~ 0_ ~; i ~ ^ ~ Q ~ ~ ~ ^~ ~ 6/3/2008 ^ s ~ ~ ^ Q ~ 6/2/2008 -- 6/1 /2008 0 ~ 0 0 N O 0 0 0 00 CO ~t 0 0 N O 0 00 0 0 0 CO ~ N 0 ~ r M N r r O O O e- ti Cfl ~ M N ~ (ddb) awn~on pue a;eanno~_~ PTD 167-026 Beaver Creek #2 May 2008 Injection Summary Page 1 of 1 • • Regg, James B (DOA) From: Donovan Jr, Dennis M. [ddonovan@marathonoil.com] Sent; Tuesday, June 03, 2008 11:17 AM `~~ ~(~I~~ To: Regg, James B (DOA} Cc: Donovan Jr, Dennis M.; Skiba, Kevin J. Subject: PTD 167-026 Beaver Creek #2 May 2008 Injection Summary Attachments: BC2 May 2008 Injection Summary PTD167026.x1s Jim, / Attached is the May 2008 Injection Summary for Beaver Creek #2 (PTD 167-026). Inner Annulus pressure has remained below 1000psig per Sundry 308-093 with periodic blow downs. Outer Annulus has not changed it remains at -Opsig ./ Thanks, Dennis Dennis ~L. Donovan fir. Production Engineer I 907-283-1333 Office 907-398-1362 Cell «BC2 May 2008 Injection Summary PTD167026.x1s» ~~l~1~Ep JUN 1 ~. 2008 6/3/2008 ~~ e~ E N m ._ 0 0 N ea N m °o ~° O I~ M N (6isd) a~nssa~d n °o °n °o ~°n °o ~° °o 0 l!') N O ~ ~ N O I N N N ~ ~ ~ r- ti • 0 n O I 0 ~ n N O - T~ - -----r ---- --- --_ T, 6/1 /2008 ~, , ~ ~ ^ 5/31 /2008 ~, • ~ ^ 5/30/2008 .wow ~~^ ^ 5/29/2008 ~ ~ ' ~ ~ 5/28/2008 : ~ r.jr~ . ~^ ^~^ ~ _ Q ' ^ 5/27/2008 ~- a~ ~ ~ ~ ~ ~ I 5/26/2008 ~ ~ Nr ^ 5/25/2008 • i ~~ : ^ ' ~ • ~ ~ !i ^ 5/24/2008 f ~ rn ' ~ ^ ' 5/23/2008 • ~ ^ 5/22/2008 ~ ~ ~ ~ i ^ 5/21 /2008 • ~ ' ., i~~.~r! ~ ~ ', ! ^ 5/20/2008 a m ~'«.+~~ ~' ! ^ 5/19/2008 m ~ rr~M~~~ j ^ 5/18/2008 > M~~M ~!• ••• ~ ' ~ ' : , 5/17/2008 ~ ~ : ~ni •: i« a ~ • ^ ~ 5/16/2008 ~ i m .r w •• t • ~:; ~•r,: , F= a~ 5/15/2008 'c ~ .,,~~•, • NR • • ^ ~ i• i.~ • i~i:• ~~ ~ ~~ ', ^ 5/14/2008 °` a, • i. '~•"" _ • ~. •• ~^/r' ~' ^ 5/13/2008 ~ °- wr • • • • ^ 5/12/2008 ~ ~~~~ ~ Y~ '~' ~ ; ; 5/11/2008 Q .~~• ~ ~,•~ ^ 5/10/2008 ~ +""~ ' ' ^ 5/9/2008 •t•~'~ ~ 5/8/2008 ~~. • • •; • ' a ! ~~ _ ,'~+,=1 ; ^ 5/7/2008 .., t ~ ! ^ 5/6/2008 ~ •*S 1 K•ti~'f ^ 5/5/2008 o ~+^• a • • M • •~r~l~ ^ 5/4/2008 ~ ~ a • • ~ •. i ,I ~ ~ •~'•'•• ~ i ~ ~!, ^ 5/3/2008 N•',•~•'•• ~ ~ ~ ' ^ 5/2/2008 • • • ~ • • • ~~*"TM ~ 5/1 /2008 4/30/2008 0 0 0 0 0 0 0 0 0 0 0 0 0 ~ N O 00 Cfl ~ N O CO Cfl ~ N ~ M N O O O ~ Cfl ~T' M N ~ r r r r (ddb) awn~on pue a~e~nnol~ • • ~~_Z ~ ~'~ 167- ~~~~ l Inner An nulus Pressure Bleeds Date Time Pressure (before) Pressure (after) 5/9/2008 3:30 596 315 5/13/2008 5:00 637 441 5/13/2008 15:30 482 376 5/17/2008 7:26 616 541 5/19/2008 7:30 660 525 5/21 /2008 10:30 636 421 5/22/2008 14:51 414 337 Outer An nulus Pressure Bl eeds Date Time Pressure before) Pressure after None None None None R Ja • ~ ~ ~ egg, mes B (DOA) ~ ~7 0 ~, From: Donovan Jr, Dennis M. [ddonovan@marathonoil.com] Sent: Tuesday, May 06, 2008 3:51 PM To: Regg, James B (DOA) ~ ~C ;~/~j1d `~ Cc: Donovan Jr, Dennis M.; Skiba, Kevin J. CC Subject: Emailing: BC2 April 2008 Injection Summary.xls Attachments: BC2 April 2008 Injection Summary.ZlP BC2 April 2008 Injection Summa... «BC2 April 2008 Injection Summary.ZIP » Jim, Attached is the BC2 Injection Summary for the month of April 2008. As per your request, these monthly reports will be emailed to you in place of a formal letter and printed graphs. Thanks, Dennis Dennis M. Donovan Jr. ~~N JUN ~ ~ 200 Marathon Oil Company Production Engineer I 907-283-1333 Office 907-398-1362 Cell The message is ready to be sent with the following file or link attachments: BC2. April 2008 Injection Summary.xls Note: To protect against computer viruses, e-mail programs may prevent sending or receiving certain types of file attachments. Check your e-mail security settings to determine how attachments are handled. 1 • • (6~sd) a~nssa~d °o ~°n °o °n °o ~°n °o ~°n °o 0 0 0 O I~ tf) N O ~ ~ N O t,C) O tf) M N N N N ~- ~ ~ ~ ~ ~ N O ,~. -- -~ ••-M ; _M - ~, -- ~ ---r ---- --- - - 5/1 /2008 N `~ ~ "~'Vr~' ~~• .~ SK~~r ^ 4/30/2008 ~ rn ' «~.• ~ • . *•• , ^ ' 4/29/2008 ~a `. ~, off ~/rll; . N ! .~..• ~~ •: •: ~ •« ar ' ^ 4/28/2008 ~~ ~ ~ ~ ' + ~ ^ 4/27/2008 c ~ir~ • •~ • • ~ C Q I ' r#..~ ~. • • •«"~'~~ ^ 4/26/2008 N ~A ~ ~~• • • ..~ c ~ ' •^.;w .• ~ ~ ..,~• ~ ^ 4/25/2008 ' ! ""~'''"' ~ ~ ~ ^ 4/24/2008 r..r~••. •~.w~~ ~ , ~ ~~~ ~ •! ~ 4/23/2008 ~i.•a m a'=~ ' ^ .: 4/22/2008 4/21 /2008 ~' ~ • • E ' o ~~~l+~ '- s . • I ~ ^ 4/20/2008 ~ ' m I ' ~..! w^~^ 4 • • !^ 4/19/2008 ~ N c ' a~ ~•~ • • •' '~ •; ; ;~."ri~w.; ! ^ 4/18/2008 ji1°~ ~ ^ 4/17/2008 _ ' ~ ! ! .r'w. *:. ~ : ' ~• ::~ ^ 4/16/2008 E 00 ~ ~ ~~ • • • . • • ~~ °c ' ~~ ~.• • ~l+~~1~- • • rt ^ I 4/15/2008 ~ N ' ~ ~ ~. I. • .', ~i• • •~ ^ 4/14/2008 'a ~ j i ~ • • • ' ^r! • • Q .~ . • • • ^ 4/13/2008 N Q l i., S .~i- 1 V n ~ .~'..: M • '~.::'.*~~*""" ' ^ 4/12/2008 c ~. ~ s ~ ~~ • • • ^ 4/11 /2008 Q i~1i,, .•••! ! 1 w • ; •• • •~ ^ ~ 4/10/2008 ~ i ~i i'i i1•• • Z': ~ ~ • ~ • ~ • j •• ' ^ 4/9/2008 „ ! •~r. • ~ ~ P ~,* 1~ j • 4/8/2008 a 4/7/2008 m ~' I I 4/6/2008 m ~ o ' ~ ', 4/5/2008 ^ I ~ 4/4/2008 4/3/2008 ~ j 4/2/2008 ~ 4/1 /2008 0 0 0 0 0 0 0 0 0 0 0 0 0 ~ N O 00 Cfl ~ N O OO CU ~ N ~ M N O O O ~ Cfl ~ M N ~ ~ ~ r r (ddb) awn~on pue a;e~nno~~ • Inner An nulus Pressure Bl eeds Date Time Pressure (before) Pressure (after) 4/9/2008 20:00 721 622 4/11/2008 19:45 636 550 4/13/2008 21:50 626 548 4/15/2008 8:27 624 489 4/17/2008 14:00 915 539 4/20/2008 9:34 741 452 4/21 /2008 7:53 730 566 4/22/2008 6:51 832 469 4/23/2008 16:31 723 536 4/24/2008 13:44 549 492 4/25/2008 13:38 574 422 4/27/2008 15:11 694 523 4/29/2008 8:13 529 462 Outer Annulus Pressure B leeds Date Time Pressure (before Pressure after None None None None ~~' ".2~„ P~ ~J I ~~-C1zlo Marathon MARATHON Oil Company May 23, 2008 • Marathon Oil Company Alaska Asset Team P.O. Box 1949 Kenai, AK 99611 Telephone 907/283-1371 Fax 907/283-1350 ~~~~~ \/~ MAY 2 7 zoos Mr. Tom Maunder Alaska Oil ~ Gas Cons. Commission Alaska Ohl & Gas Conservation Commission Anchora e 333 W 7 Ave ~ Anchorage, Alaska 99501 Reference: Revised 10-404 Report of Sundry Well Operations Field: Beaver Creek Field Well: Beaver Creek #2 Dear Mr. Maunder: ~~i~NNE~ .lU1~ ~ ~ 2008 Attached for your records is the revise 10-404 Report of Sundry Well Operations for BC-2 well. This sundry is being submitted to correct the data entry error of the packer depth stated on the 10-404 Sundry (#307-018) submitted on August 16, 2007. The measured depth of the packer was report as 4,961' which is the depth of the tubing end. The correct measured depth of the packer is 4,923'. Please contact me at (907) 283 -1371 if you have any questions or need additional information. Sincerely, ~~;~ a S Kevin J. Skib Engineering Technician Enclosures: 10-404 Report of Sundry Well Operations cc: Houston Well File Well Schematic Kenai Well File KJS o~ STATE OF ALASKA ALA OIL AND GAS CONSERVATION COM ION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon Repair Well Plug Perforations Stimulate Other ~ /Revised Packer Performed: Alter Casing ^ Pull Tubing ^ Perforate New Pool ^ Waiver^ Time Extension ^ Depth Change Approved Program ^ Operat. Shutdown ^ Perforate ^ Re-enter Suspended Well ^ 2. Operator Marathon Oil Company N 4. Well Class Before Work: 5. Permit to Drill Number: ame: Development ^ Exploratory^ 167-026 ' 3. Address: Stratigraphic ^ Service^ 6. API Number: PO Box 1949, Kenai Alaska, 99611-1949 50-133-20021-00-00 7. KB Elevation (ft): 9. Well Name and Number: 155' (15' AGL ~ Beaver Creek # 2 ' 8. Property Designation: 10. Field/Pool(s): FEDA 028118 i Beaver Creek Field /Sterling Pool 11. Present Well Condition Summary: Total Depth measured 15,697' ~ feet Plugs (measured) 5,197' true vertical 15,697' ~ feet Junk (measured) p Effective Depth measured 5,197' feet true vertical 7~890~ feet Casing Length Size MD TVD Burst Collapse Structural 265' 20" 280' 280' NA NA Conductor Surface 2,196' 13-3/8" 2,211' 2,211' 3,450' 1,950' Intermediate 8,820' 9-5/8" 8,835' 8,835' 6,330' 3,810' Production 10,171' 7" 15,439' 15,439' 8,160' 7,020' Liner 25g' 5" 15,697' 15,697' 10,140' 0 Perforation depth: Measured depth: 5,007' - 5,220' True Vertical depth: 5,007 - 5,220' Tubing: (size, grade, and measured depth) 3-1/2" N - 80 4,961' ~~~~® AY ~ Packers and SSSV (type and measured depth) Baker FH Packer ~ ~~~~ 4,925' ~t asks Di1 ~ ~. ;: 12. Stimulation or cement squeeze summary: ` ' n11SS~®d~ AOCtiQ ' Intervals treated (measured): 1 8 ~ Treatment descriptions including volumes used and final pressure : 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: NA NA NA NA NA Subsequent to operation: NA NA NA NA NA 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run NA Exploratory ^ Development ^ Service^ Daily Report of Well Operations NA 16. Well Status after work: Oil ^ Gas ^ WAG ^ GINJ ^ WINJ ^ WDSPL Q 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: 307- 018 Contact Kevin Skiba (907) 283-1371 Printed Name Kevin J. Skiba Title Engineering Technician Signature Phone (907) 283-1371 Date May 23, 2008 Form 10-404 Revised 04/2006 - +d ~~~*• ~~~ ~ q 7~DS bmit Original Only it #: 167-026 50-133-20021-00-00 ~rtv Des: FEDA - 028118 15' AGL (155' KB Elevation) Date: 7/13/1967 ate: 11 /9/1967 eleased: 09:OOhrs 12/26/1967 Perforations: Sterling B-1: 5,007'-5,028' 5,032'-5,052' Sterling B-2: 5,125'-5,140' Sterling B-3: 5,155'-5,220' Isolated Perforati ons: Sterling B-3a: 5,230'-5,244' squeezed B-3a: 5,263'-5,265' Sterling B-4: 5,324'-5,344' BV~~ Pad 2 (Injection Well) 590' FNL, 1,979' FEL Sec. 3, T6N, R10W, S.M. =ra c ~ f~ ~ c ~ ~ F~II @ t~ 5,132' SLM ~_~ (11/11/01) Cement Cap @ 5,197' ~ c Cement Retainer @ 5,221' ~ try ~r IC ~ c r ' 7' Liner stub 5,268' r ' 7" liner shoe 15,439' 5" liner shoe 15,697' TD = 15,697' MD &TVD 20" H-40 94 ppf Top Bottom MD 0' 280' TVD 0' 280' Cmt/w 525 sacks 13-3/8" N-80 & J-55 74 ppf Top Bottom MD 0' 2,211' TVD 0' 2,211' Cmt/w 2,000 sacks Intermediate 40 ppf 9-5/8" N-80 & S-95 43.5 ppf 47 ppf ToD Bottom MD 0' 8,835' TVD 0' 8,835' Cmt w/ 1,370 sacks Production Liner 29 ppf 7" N-80 & P-110 32 ppf Top Bottom MD 5,268 15,439' TVD 5,268' 15,439' Cmt w/ 650 sacks Liner 5" N-80 18 ppf FJ Hydrill ToD Bottom MD 15,415' 15,697' TVD 15,415' 15,697' Cmt w/ 41 sacks Production Tubing 3-1 /2" N-80 9.2 ppf Otis XA circ sleeve 4,889' Baker FH hyd packer 4,923' Baker WL entry guide 4,961' Well Name & Number: Beaver Creek #2 Class II Disposal Well Lease: Beaver Creek Unit, Pad 2 County or Parish: Kenai Penisula Borough State/Prov.: Alaska Date Completed: RKB: 15' Country: USA Angle/Perfs: Angle @ KOP and Depth: 0° KOP TVD: Ground level: 140' Prepared By: Kevin Skiba Last Revision Date: 3/19/2008 0 4 Alaska Asset Team Marathon MARATHON Oil Company PO BOX 1949 Kenai, AK 99611-1949 Telephone 907/283-1371 Fax 907/283-1350 ~~ ~~~ ~ ~ ~~u~(~ May 1, 2007 ~, . Alaska Oii ~ (gas Cons. Cammission ~~A.~~E~ JUL ~.:~ 2008 Anchorage Tom Maunder AOGCC 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Reference: April 2008 Report of Disposal Injection Operations Well BC-2, Beaver Creek Unit (PTD 167-026) Sundry 10-403, Sundry #308-093 Dear Mr. Maunder: This monthly report of disposal operations covers the period of April 1St 2008 through April 30th 2008 for well BC-2 located in the Beaver Creek Unit. Disposal via well BC-2 is governed by Disposal Injection Order (DIO) No. 4 for the Beaver Creek Unit (approved June 1st, 1987) As per sundry #308-093 this report is required. During the report period, routine periodic blowdowns on the tubing/casing annulus maintained an annulus pressure less than 1000psig. There was no indication of pressure communication with the outer annulus. Attachments include a monthly report of April 2008 injection summary. All wellhead pressures, injection rates, and pressure bleeds are included. Sincerely, ~~ Dennis M Donovan Jr Production Engineer I Marathon Oil Company Enclosures . ., 0 rn m D 3 7 C C N ^ c Q ~.~ C c • j 0 o c c 800Zllftr -- --fi--- 8(IOZiZtb 804Z1£!b SOOZItrIb 800Z191b 804Z191b goa~ttw I I?oaztel~ ^ f g00Z16~W ^ .~ SOOZIOIftr ^ ~; s4ozl l ~rtr ~ ^ SOOZfZ llti ' ^ '' so0zr~ lrtr ^ 844ZIti llb ^ 900ZfSlttr ^ 3 844Z191tb ^ it eoaztc ~tb ^ 800ZI8 llb ^ I• r • • n • • • •• ~ ~ •~ . ~•••• • • e ~ • M• r 7~•••• • • ~ • . • ~ • •wr ry~••••s r ~R • f; ••Mr ~~i1.1 ~" +} ~ i!''~ r•: r + • s w f.. ~ I •r~ • ~ f 1 ~ ~ • • • '+ r a f 't -r ~' ~r• ••~i + . .• ••r . •. ~ 6 .~ • ~.. ~ • ..r,• ~ .r f •° ~ '~ ~ • • A N• ~••~~ } • • ~~ t • • • .... Flowrato and Volumo (®PD) J ~ ~ c a ~" ~ g _- ! -_-- 900216 llti~ ^ ~ • • • • ~ •~ ~ ~ ^•r•• •i 90DZ10Z/V ^ ' • ~ • • ~ ~ • } • ~ • • • -• ~ • • ~~^ 80021 l Zld ^ 800Z2Z1tr ~ I ^ eoozr£zrt soozrozrtr SOOZfSZItr SOOZf9Zltr ^ ^ 844Zt1 ZIb ^ r sooztezrb ^ 800Zt6Ztb ^ 900ZI(YEIti ^ ~ BoOZr ll5 _ _ O N (,h cn o O Q ... .... .. ~. .•.• ...,. --- ..i.. ~ ~.... .. • . • •• s s s s • { ~...a•~+ a• ~~ • • • i • • • • ~ •+~ ~ .. ~ . r j r- a +r4. }~'''~ + • ~ i c o 'J ~ j -+ -~ N IV N N w U1 O N (,h ~ Q N (Q~ ~1 O ° ~ ~ O O ~ O c~ c °o Pressure (pstg) ~•. n N D ~. N O O CO `. .art O N c d r ~ Inner Anlwlera Pressure Bl e~a~ Date Tune Pr65t8iJre before Pn~asure r 419(2DGB 20:90 729 622 4111!2048 19:45 898 55p 4113,"200$ 21:5{! 826 54$ 4(15,'2008 8 27 82~ 489 4117J2008 14;U4 915 539 4'241200$ n_34 . 741 432 4!2112048 7.53 734 5G6 41221200$ 6.51 $32 469 4'2312008 16:3' 723 53S 41241.2908 93:44... 549 482 4125/2908 13:38 574 422 ............ 4!2712008 15:11 694 523 4'2912008 8:13 529 462 t3ufer Annulus Pr$ssurs B leeds Date Time Pressure be#ore Pressure ~dolle P14rle fdOn6 Norse Beaver Creek #2 : PTD#167-026 Page 1 of 2 Regg, James B (DOA) • • From: Re99, James B (DOA) ~' f,~.` ~f ~ Sent: Wednesday, April 09, 2008 11:18 AM ~ t To: 'Walsh, Ken' Subject: RE: Beaver Creek #2 : PTD#167-026 1'll offer some clarification regarding the maximum allowable tubing-casing annulus pressure (1000 psi) per Sundry 308- 093. Max allowable means do not exceed; Marathon must take action (bleed pressure) before exceeding 1000 psi. Points 1 and 2 accurately capture our discussions. Jim Regg Aoocc ~K;~~I~~® MAY ~ 2008 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 phone: 907-793-1236 fax: 907-276-7542 From: Walsh, Ken [mailto:kdwalsh@marathonoil.com] Sent: Friday, April 04, 2008 11:59 AM To: Regg, James B (DOA) Cc: Ibele, Lyndon; Schoffmann, A B (Ben); Skiba, Kevin J.; Walsh, Ken; Turkington, Jeffrey A. Subject: Beaver Creek #2 : PTD#167-026 Jim, l am sending this email as a follow-up to our telephone conversation on Tuesday, April 1, 2008 regarding reinstating water injection into the Beaver Creek #2 well. l wanted to confirm the following items of agreement with you: 1. The AOGCG has provided verbal and written approval to immediately start injecting produced water into this well. The telephone conversations took place between yourself and Lyndon Ibele with Marathon Oil on March 14 and with me On April 1. The written approval was provided by AOGCG signature of the Form 10-403 Sundry #308-093 waiver request submitted to Tom Maunder. 2. I stated i our telephone conversation that I was beginning to investigate a suitable method to try to identify the source of the sporadic and one-way communication from the tubing to the inner annulus that was described in greater detail in the cover letter that accompanied the waiver request. You stated that no additional formal paperwork other than that stipulated on the waiver was necessary to proceed with injection in this well. You also requested that should l decide an a testing procedure that l provide an email to you describing the proposed testing and an email after the testing to describe what was learned. So far, I have not been able to arrive at a procedure that would pinpoint the source of this leak without potentially jeopardizing the tubulars. 3. fine of the stipulations that the AOGCC included on the approved 10-403 waiver request was that '°aximum allowable tubing-casing annulus pressure is 1000 psi," I believe that when we spoke on the April 1 you were aware that this annulus pressure has spiked to 1500 psi during at least one of the injection periods. You requested that Marathon remain vigilant in observing this annulus pressure and ensure that anytime the pressure in this annulus exceeds 1000 psi that we bleed the pressure down below 1000 psi in a timely manner. 4/9/2008 Beaver Creek #2 : PTD#167-026 Page 2 of 2 Please sand me an email to ca~-n that you agree with these point Respectfully, .7~~ 4/9/2008 Regg, James B (DOA) • ~J i~~~o From: Schoffmann, A B (Ben) [abschoffmann@marathonoil.com] Sent: Friday, March 28, 2008 10:12 PM ~ To: Regg, James B (DOA) ~~ 2 ~ ~ ~ (~~' Cc: Schoffmann, A B (Ben}; Ibele, Lyndon; Walsh, Ken; Laughlin, Gary A.; Turkington, Jeffrey A. Subject: Beaver Creek #2 Injection Page 1 of 1 Jim, Wei(, it seems Friday evenings are the time for our injection well BC-2 to act up. We had another event this evening. ~ left you a voice mail message sometime after 6:30 pm that we saw pressure on the first annulus increase to in excess of 1000 psig late this afternoon. ' When I had been advised of the situation just before I called you, our operators had already ceased injection and were preparing to attempt to blow down the annulus. It appears this event was more rapid and to a higher pressure than the others we have reported and discussed, so we are erring on the side of caution. We plan to leave the well shut in over the weekend and would like to discuss options with you on Monday after we have had a chance to consider possible explanations and remedies. We do not intend to restart at least until after we have had a chance to review the information visit with AOGCC. I will try to have a pressure plot sent to you in preparation for that. -% .~~,~-~- 3j3t'p~ Please advise if you have any questions or need other information. Thanks, Ben 4 ~ I ~Za'~ _. - ~ ~~ j l~ ~-s~. C~,tcu~-t~~,, ; zr~ ~- ~~ i ~~) ~- t,~1( rem ~ „~ ~ ; d l scu s % ~ l.~ ~ ~,T.n s},` c c,~~-uws - ~=,1~ h~n.~ ~~- ~~ o~ -~ ~~~ec~- wti~ 1?C.- Z -wr l~c~c~v~fi'cs , O~rcc`~ ~ f ~~ Ca~~v{' e..~z-cr.S ~ C.~~~~~uSL ~-~. ~~r~ SOS- c~13 ~a 31 Z~6,Z~ ~ ~t~~N~ APR ~ ~ 2008 4/ 1 /2008 ,.~! x Fie Edit View Favorites Tools Help ~~ 3/272008 12:00:00 AM ~~ Iy3/30/2008 11:59:59 PM ;3127,•'2008 2..23:5? 6M'; <" psi (!/y0/740N 9:J9:54 4M) 2 pYl '044 5004 144 124 1406 ua'ti!dKe 4 pnl(2 derK, 19:1Z'44) \~ !~"~ ~ .~ . ~ ~i ~ • , 44 4 3(T7,fZ4g8 3fZ7fZ40i9 ! Z;4n;gq ZM x:11:59 pM ~:~7~SC hhd Q .C: ABC2_Well_2_FR BC WeN 2 Injection Flow Rate ^~ ,,,,, ABC2_Well_2_Inner PT BC WeN 2 Injection Casing Inner Psi 0 ~ BC WeN 2 Injection Casing 6uter Psi .j,i ABC2_Well_2~Ternp BC WeN 2 Injection Temp ^~ .l„ ABC2_WeN_2 Tubing_PT BC WeN 2 Injection Tubing Psi Dona ~ ~~ ~ fly, ;~~yy~ ~~,`'J ~' ~ ~~~ r~ ~ 89.39.4.138:ABC2_WeN_2 Inner PT ~ Value: 1504 Time: 3(28f2008 6:35:29.133 PM ~ n, dr.. • r .,.1 .S RM 9:35:59 AM 89.39,a.138:AgCZ„Y~e11~2r0uter~F~T (C'yClitJ ~__~ Color Units 1 BPD ~... i,... 7 F `' . 11:59:59 PM • • '~ Local Intranet • BCU-2_IA_repressurization_TIO_pressures_2008-0331.txt BC-2 TrendsFrom: schoffmann, A B (Ben) [abschoffmann@marathonoil.com] Sent: Monday, March 31, 2008 7:12 AM To: Regg, James B (DOA) ~~~^~sC q'f ~ Cc: Ibele, Lyndon; Walsh, Ken; schoffmann, A B (Ben) ~ ~I~ 1 subject: Fw: BC-2 Trends Jim, As I promised, here is a plot of BC 2's pressure during the past week. As you can see, on 3/28 the casing pressure climbed fairly steadily, causing us to SI the well and make notice to you. I have a pretty busy morning with meetings and a dental appointment (oh joy!), so maybe you could either talk to Lyndon or we can try this afternoon should you need anything else in the meantime. Thanks, Ben -------------------------------------------------------------------------------- From: Laughlin, Gary A. Sent: Mon 3/31/2008 6:29 AM To: Donovan Jr, Dennis M.; Ibele, Lyndon; Laughlin, Gary A.; Martens, Dave; ivorthcott, T J.; Paxton, Todd D.; schemanski, Raymond L.; schoffmann, A B (Ben); senette, Brent M.; skiba, Kevin J.; Walsh, Ken; Turkington, Jeffrey A. Cc: Laughlin, Gary A. Subject: BC-2 Trends Page 1 N 1~ u ,7' ,~ -~ L' L u f~ iV ALASSA OIL AHD GAS COHSERQA7`IOH COMl-IISSIOH Lyndon Ibele- Production Coordinator Marathon Oil Company PO Box 1949 Kenai, AK 99611-1949 Re: Beaver Creek, Sterling Gas Oil Pool, BC-2 Sundry Number: 308-093 SARAH PAL/N, GOVERNOR 333 W. 7th AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 ~~b7-oab ~~ N[~~ MAR ~ ~ 200 Dear Mr. Ibele: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided m 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 ff the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, Daniel T. Seamount, Jr. Chair DATED this Z7 day of March, 2008 Encl. • • M Marathon MARATHON Oil Company Marathon Oil Company Alaska Asset Team P.O. Box 1949 Kenai, AK 99611 Telephone 9071283-1371 Fax 9071283-1350 DECEIVE MAR 2 1 2008 March 19, 2008 Mr. Tom Maunder Alaska Oil & Gas Conservation Commission 333 W 7"' Ave Anchorage, Alaska 99501 Reference: 10-403 Sundry Notice Field: Beaver Creek Field Well: Beaver Creek #2 Well Permit #167-026 Dear Mr. Maunder: Alaska Oil & Gas Cons. Commission Anchorage ~,_ ._ . Marathon requests a waiver of 20 AAC 25.450(a) well integrity requirements for permitted ~ disposal injection well BC-2. As discussed with Jim Regg on March 14, 2008, there appears to be a minor, intermittent, one-way communication between the tubing and tubing/casing annulus in this well. During batch injection operations, there is a large pressure differential between the tubing-casing annulus pressure (recently observed at 500-950 psig) and the tubing pressure of approximately 2000 psig during. When injection ceases, the tubing pressure drops below the annulus pressure, however the annulus does not bleed off, indicating that it is a relatively minor one-way leak. Recall also that Marathon performed a mechanical integrity test of the tubing/casing annulus last month, with no indication of any . leakage. Marathon also continuously monitors the pressure on the outer annulus, between the 7" production casing and the 9-5/8" intermediate casing. Monitoring shows less than 1 psig on this outer annulus, indicating no evidence of communication with the 7" casing. 20 AAC 25.252(e) allows surveillance in lieu of repairs to assure mechanical integrity for injection operations. Marathon proposes that injection operations be permitted with continuous monitoring of the tubing/casing annulus pressure and the annulus between the 7" production casing and the 9-5/8" intermediate casing. It is requested that pressures on the tubing/casing annulus up to 1000 psig be permitted. Routine periodic blowdown will be conducted, if necessary, to maintain the tubing/casing annulus pressure at less than 1000 psig. If monitoring indicates any evidence of pressure communication with the outer annulus, injection operations will cease and will be immediately reported to the AOGCC. Page 1 of 2 • • Please contact me at 907-565-3042 if you have any questions or need additional information. Sincerely, ~` Lyndon C. Ibele Production Coordinator Enclosures: 10-403 Sundry Notice cc: AOGCC Houston Well File Kenai Well File KJS Page 2 of 2 KCC~CIVCV ~ ` ~ 3 ~ STATE OF ALASKA MAR 2 1 ~ ALA OIL AND GAS CONSERVATION COM~SION , APPLICATION FOR SUNDRY APPROVgia Oil & Gas Cons. minion 20 AAC 25.280 1. Type of Request: Abandon ^ Suspend ^ Operational shutdown ^ Perforate ^ Waiver ~ - Other ^ Alter casing ^ Repair well ^ Plug Perforations ^ Stimulate ^ Time Extension [] Change approved program ^ PuII Tubing ^ Perforate New Pool ^ Re-enter Suspended Well ^ 2. Operator Name: Marathon OII COI'1'1p111~/ 4. Current Well Class: 5. Permit to Drill Number: Development ^ Exploratory ^ w 167-026 3. Address: p0 Box 1949 Stratigraphic ^ Service ^ 6. API Number: Kenai Alaska, 99611-1949 ~ 50-133-20021-00-00 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: Spacing Exception Required? Yes ^ No ^~ '`°` Beaver Creek # 2 9. Property Designation: 10. KB Elevation (ft): 11. Field/Pool(s): ~~~,.~ FEDA 028118 ~ 155' ' Beaver Creek Field /Sterling Poo 12. PRESENT WELL CONDITION SUMMARY ' 3 u-~ `'~' Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk(measured): 15,697' 15,697' 5,197' 5,197' 5,197' NA Casing Length Size MD TYD Burst Collapse Structural 265' 20" 280' 280' NA NA Conductor Surface 2,196' 13-3/8" 2,211' 2,211' 3,450 psi 1,950 psi Intermediate 8,820' 9-5/8" 8,835' 8,835' 6,330 psi 3,810 psi Production 10,171' 7" 15,439' 15,439' 8,160 psi 7,020 psi Liner 258' 5" 15,697' 15,697' 10,140 psi 10,490 psi Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 5,007' - 5,220' 5,007' - 5,220' 3-1/2" N - 80 4,961' Packers and SSSV Type: Packers and SSSV MD (ft): Baker FH Packer 4,961' 13. Attachments: Description Summary of Proposal ^ 14. Well Class after proposed work: Detailed Operations Program ^ BOP Sketch ^ Exploratory ^ Development Q Service ^ 15. Estimated Date for 16. Well Status after proposed work: Commencing Operations: Oil ^ Gas ^ Plugged ^ Abandoned ^ 17. Verbal Approval: Date: 3/14/2008 WAG ^ GINJ ^ WINJ 0 WDSPL ^ Commission Representative: James Regg 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Kevin Skiba (907) 283-1371 Printed Name L bete Title Production Coordinator Signature Phone Date , ~' (907) 565-3042 March 19, 2008 , COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Plug Integrity ^ BOP Test ^ Mechanical Inte rity Test ~ Location Clearance ^ ~ c s e - l,~, ~~1~~~/ . v Other: ~ (^e~~ tA,~4u'lF1tA ~~~L'~S `~ ~~jrt'~rr~ rtc~ GtLllila~ ' S~.u~ nwn~ ~~,,.~- ~ weli ~,~d P!'ess4L-,~s ~ ~n~eG~z~;-~ IYZ.~~, ~ ~ PR?s5ie:~ bie~eCs~z~r ezl.l ~n.~t,` Nla.lt)ftu~.~ C~((c7w~c.b~ ~cc'.~ ` cet ,::~ ar..u~L.~S ~2~scc~~ ~`S tovc~~~ ` ~ . ~ ~n l,t.Z°.l, (S M~.Gt'iCC,t i CQ ti ~-0110 ~'('~ c; U ~ I~~Mf? C(i R.`~- ~~~c~ ) /~'~ ~ ' ~ ~•!~ i S .j CLU.Ctt,-~ i 'j r 'ZC~ ~3 inn+' ~1(il'Set ~ C~C1-~ 'fz+.~- z~{ f Subsequent Form Required: ~ `n tOA'~iti~- `~ t:Cf.tt'C?~ t,c,%Lt6~~'- APPROVED BY f ~~ Approved by: COMMISSIONED T COMMISSION Date: ~ f/ v'~~~ i - ' Form 10-403 Revised 06/2006 9 ~ ~`1'~,~ S mit in Duplicate. Beaver Creek Water Disposal Well BC-2 Page 1 of 2 Regg, James B (DOA) Jlo 1 _ ~~~ From: Regg, James B (DOA) Sent: Tuesday, March 18, 2008 2:50 PM ~ To: 'Schoffmann, A B (Ben)'; Maunder, Thomas E (DOA) ~ 3)t~ ~~~ Cc: Ibele, Lyndon; Walsh, Ken (, ` Subject: RE: Beaver Creek Water Disposal Well BC-2 Ben - Thought it might be helpful to reiterate several points about our process. Based on what I have reviewed, we can approve the waiver for continued injection in BC-2 (PTD 167-026) with increased surveillance. The well may remain on injection while we work through the waiver process. Marathon should send a 10-403 requesting a waiver far mechanical integrity reasons; there is a "Waiver" bax in the header of the farm; please also attach a brief explanation of the reason for the waiver request (info provided below is appropriate}; you do not need to resend the pressure plot, well schematic, and the MITs done in the recent past -those are all on file here; You may make recommendations for surveillance, max allowable pressure limit, etc. far our consideration (in lieu of making repairs}; 20 AAC 25.252(e) allows surveillance in lieu of repairs, Waiver request falls under 20 AAC 25.450(a} since there is no administrative approval clause and no specific info regarding well integrity requirements in Disposal Injection Order 4. Jim Regg AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 phone: 907-793-1236 fax: 907-276-7542 ~~ MAR ~ ~ 200 From: Schoffmann, A B (Ben) [mailto:abschoffmann@marathonoil.com] Sent: Friday, March 14, 2008 2:43 PM To: Maunder, Thomas E (DOA); Regg, James B (DOA) Cc: Ibele, Lyndon; Walsh, Ken; Schoffmann, A B (Ben) Subject: Beaver Creek Water Disposal Well BC-2 Tom and Jim, Confirming the phone call we just had regarding BC-2, we saw pressure increase on the first annulus again subsequent to the additional MIT we did in January. We blew down the 1st annulus it down last night, but I had asked our field personnel to cease injection into BC-2 until at least we communicate with you. On our phone call, you gave permission to ~~continue injection, and requested this a-mail and some additional information. See below for additional details. As discussed, there may be a small, intermittent, one-way communication between the tubin and tubing/casing annulus. Under normal injection conditions, there is a pretty big differential from the first annulus pressure (500-950 psig range) vs injection pressure at around 2000 psig. Once injection ceases, the tubing pressure will drop below the annulus pressure, but the annulus does not appear bleed off once injection stops, indicating it would be a fairly minor one-way leak. Please be advised that, as we discussed, the second annulus appears to be just fine with only 1 psig of pressure, so if there is a leak, it appears to be contained from any fresh water sources. You also requested a plot of the well pressures. I will get our team working on that and see if we can send it you on Monday as we discussed. Lyndon Ibele and/or I will be happy to discuss potential enhanced monitoring options as well. Please let us know if you need any further information. Thanks for your consideration and for confirming your permission to continue injection at this time. 3/19/2008 Beaver Creek Water Disposal Well BC-2 Regards, gew Ben Schoffmann Operations Manager Marathon Oil Company work: 907-565-3035 cell: 907-748-3589 fax: 907-565-3076 Vile are SAFE -CLEAN -RESPONSIBLE -every day, every way ~iet~ ~ ~;te s Page 2 of 2 ._ ~~ G w~ GCG~NI,tn~s~~Z~ ~-~'~(~r~v~. Gtcc~.~~ j /~~ v.~e~-~ ~,~~J. n~ r~s / -"~ '-~o ~~~e~,'~C~ ~tc..<~S Z~7fl,P~-e Z5•ZSZ ~.n~ Z~.45~ ~ ~• ~: u.c~e,~-s ~-~~,~.! 16~ ~ ~J~ ~ `3C i.~ aru( /¢ µ:~(~ ~~ cv~ K ^~~ - ~ A-~ c. ZS . 2 Sv ~~~ ~u,t~~~S ~,~, ~ ~,~:, ~cor~.-c~,;v~ c~c~,~. car , ~c re~.s~=~~ I ~ C~(.lJ'U~1~~~'LCC~ t~ ~C~'i-U 1~-kcEt~t•~~ cr~ pt~'_~SLL,t,"~_ C'9~1~--~!-tni~~~,vr~ ~-~ ~e lac z`S~~ ~~ ~a,) c~.~s ~ vw-~~~~ ~, I ess s~ ~ ~.~ c~~~ vac ~~,~ ~ ~ ~~ ~r~~-z ~ ~ St.~tL:-~~ ~.i; l ~ ~~ r'~~-c~lt r/~ c2,~ i ~.c~~ f 's~ u~ ~-~~~ 3/19/2008 FW: BC 2 March 2008 Issue.pdf Page 1 of 1 Regg, James B (DOA) i I ~ From: Schoffmann, A B (Ben) [abschoffmann@marathonoil.com] Sent: Friday, March 14, 2008 2:54 PM ) To: Regg, James B (DOA) ~~ ~ ~6 ~ 7~ ~~ Cc: lbele, Lyndon; Walsh, Ken; Schoffmann, A B (Ben) Subject: FW: BC 2 March 2008 Issue.pdf Attachments: BC 2 March 2008 Issue.ZlP / Jim, Here is the plot of BG2 pressures as you requested. ~ Regards; gew Ben Schoffmann Operations Manager Marathon Oil Company work: 907-565-3035 cell: 907-748-3589 fax: 907-565-307& e are SAFE -CLEAN - ESP SIL -eve day, every way From: Laughlin, Gary A. Sent: Friday, March 14, 2008 2:50 PM To: Schoffmann, A B (Ben) Subject: BC 2 March 2008 Issue.pdf «BC 2 March 2008 Issue.ZlP» 3/17/2008 BC 2 - recce ssas=?.~: ~ ea o:~. ... u:u:aa) .~:~; P:• lia ans waa ;x; t;zat::at:ss PP43474 Pay . i4oo sai _._ j ` t ~ i;~: ~ . s ~ ~~ ~= tom ~~ r - ! f ( ~t f: ti • s • : ~ : , • 1\s { ~ ~ • --}-- NF Dl~SS~ti`'~ ° -' _ -- 1 ~ .. R* 3:~ ^..'+H )IIS iTY19 1 ~4' t241: ~ W 414 I l:iY.~. !I.•"T?~N ;,5t2a6 1.:3553 PN .--,.: .-ue li-.ti:1?lM ILT4 :54 PM 1434+ '-+8q! 0 w 4802 wd 2 FP ~ BC Wd 21ryx1m Flown ~~ i... ~ BPD 80000.000 0,s PBt _Wd 21rca PT BC Wd2lryeclm Ca:rpl I ps' am~.~0 m,. m;z wnY 2_]uter PT BC Wd2b~xtion Coup OV Pa Pn 00000.000 OAPHC2 wd2TWtpyi BC Wd2lryeclion Tubrq Pu pa 00000.000 6 f~SSv~ bl~Pr~'S ~(C~SS Uv`E b~ee~s 3/14/2008 2:49:20 PM M:\SCADA\SCADA TRENDS\BC 2.aaTrend • • Page 1 of 1 Regg, James B (DOA) From: Regg, James B (DOA) ~ l6'7r vZ~ Sent: Wednesday, January 16, 2008 9:01 AM $C~-Z~- To: 'Skiba, Kevin J.' Cc: Maunder, Thomas E (DOA) Subject: MIT Form -Beaver Creek Pressure Anomaly Attachments: MIT Form OA 11-27-07.x1s; example_TIO_pressures.pdf MIT report form attached; please fill in information for BC-2 MIT done yesterday. I have also included an example graph of tubing/inner annulus/outer annulus pressures (TIO pressure plot). I will need something similar for Beaver Creek 2. Jim Regg AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 phone: 907-793-1236 fax: 907-276-7542 ~~~ JAN ~ ~ 2DQ~ 1 /16/2008 • • Regg, James B (DOA) From: Maunder, Thomas E (DOA) Sent: Saturday, January 12, 2008 7:01 AM ~; {~ ~ ~~ 2~ To: Regg, James B (DOA) Subject: FW: BCU-2 pressure anomaly ~C~ -Z~. -----Original Message----- From: Ibele, Lyndon [mailto:lcibeleCmarathonoil.com] Sent: Fri 1/11/2008 6:53 PM To: Maunder, Thomas E (DOA) Cc: Schoffmann, A B (Ben); Schemanski, Raymond L.; Walsh, Ken Subject: BCU-2 pressure anomaly Tom-- As I advised you by telephone a few minutes ago, I just became aware of a pressure anomaly which was observed in the casing annulus of produced water injection well BCU-2 at our Beaver Creek lease. As I indicated to you, subsequent monitoring and operations have not indicated any further evidence of a problem, however we intend to perform a mechanical integrity test next week to confirm that there is not a problem. Let us know on Mondy if you would like to have a commission witness, or if not, we will advise you of results on the day the test is performed. Below are the details as reported to me this evening: There are two casing annuli that are being monitored continuously. Per the trending the outer casing has been below 1 psi. However the inner casing recorded an increase from 450 psi to +/-1000 psi range on 12-17-08. The operators bled the pressure down to 660 psi on 12-26-08 and it held there until 1-5-07 when the operators bleed it down a second time to 500 psi and it's been holding there ever since. Looking at the graphed data, the pressure increases on the inner annulus happened over three injection periods (7 hrs total), with the pressure flat-lining between pump runs. It looks like it could have been a one way leak at the time, however it has not repeated itself since. We will fbllow up with you on Monday. 1 BC-2 Water Injection Well MIT t 01/15/08 Page 1 of 1 • Regg, James B (DOA) ~ 167-+`;~, From: Skiba, Kevin J. [kskiba@marathonoil.com] Sent: Wednesday, January 16, 2008 1:32 PM ~~ ~ , ~l~o ~;~ ° To: Regg, James B (DOA) Cc: Schemanski, Raymond L.; Icibele@marathonoil.com; Schoffmann, A B (Ben); kdwalsh@marathonoil.com Subject: BC-2 Water Injection Well MIT Test 01/15/08 Attachments: BC-2 MIT Test 011508.x1s; BC-2 Inner casing PSI Increase 12-17-08.jpg; BC-2 Injection Well MIT 1- 15-08.jpg; BC-2 Injection Well 30 days.jpg «BC-2 MIT Test 011508.x1s» «BC-2 Inner casing PSI Increase 12-17-08.jpg» «BC-2 Injection Well MIT 1-15- 08.jpg» «BC-2 Injection Well 30 days.jpg» Jim, Here is the MIT test information for BC-2 well. Also attached are the pressure trends for the past 30 days along with tend of the anomaly. Please let me know if you need any additional information. Thanks, Kevin Skiba Production Technician Marathon Oil Company Office (907) 283-1371 Cell (907) 394-1332 Fax (907) 283-1350 1/16/2008 • • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Email to:jim.regg@alaska.gov; tom.maunder@alaska.gov;bob.fleckenstein@alaska.gov;doa.aogcc.prudhoe.bay@alaska.gov OPERATOR: Marathon Oil Company FIELD /UNIT /PAD: Beaver Creek Unit /Pad 2 ~ t't ~ ~~ `~ DATE: 01/15/08 ~~ OPERATOR REP: Ray Schemanski AOGCC REP: Not Witnessed Packer Depth Pretest Initial 15 Min. 30 Min. Well BC-2 T e Inj. W TVD 4,923' Tubing 237 1,718 1,048 736 Interval V P.T.D. 167-026 T petest P Test psi 1,794 Casing 500 1,794 1,782 1,778 P/F P Notes: Test performed because of unexplained pressure increase OA 0 0 0 0 on inner casing 12/17/07. The tubing pressure was not See trend in well file for additional information. stable during test due to the effects associated with a '-"rte P[~SS~.ve Z*~'` ~~ cc,~ ~`~~%t pump injection cycle. ,i ~~.~., ' f- L~~ WeII T pe Inj. TVD Tubing Interval P.T.D. T e test Test si Casin P/F Notes: OA Well Type In'. TVD Tubing Interval P.T.D. Type test Test si Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Ty e test Test psi Casing P/F Notes: OA TYPE INJ Codes D =Drilling Waste G=Gas I =Industrial Wastewater N =Not Injecting W = Water TYPE TEST Codes M =Annulus Monitoring P =Standard Pressure Test R =Internal Radioactive Tracer Survey A =Temperature Anomaly Survey D =Differential Temperature Test INTERVAL Codes I =Initial Test 4 =Four Year Cycle V =Required by Variance T =Test during Workover O =Other (describe in notes) MIT Report Form BFL 11 J27/07 BC-2 MIT Test 011508.x1s ~~,~ Cm~ ~ t,l~.~f ~ z ~~ X67- o~ # Z .Zn ~ ~ c T7 o n GUe I ~ L ~ s f- 3 4 C~(ot yS ]-rt» ?~? Iraq. Wn11,- fax,'x~/maaa ~:~ras nM~ ~.rs~ ~~ {!/I i~x~xse ~~4t. aM~ t4.11R ~ i~~,t It n garp ~;h!'ct ~'y~~,rtatG p~ !~,-~7-OS ~aa iaa.caa a,om i.. ~`i~ lpSfl ~', ~ ~ i eP+"Kt~/` ~O ~i~ ,~MYIPr LS~q "'~,.,:~.-L+,r"~"°..'-^~hw", ,.~ 0 J ! ", i~..,,h~... .- ,..- \ ~ ` ~r any,., ~",n„+., ioy~ Pr> ~n 6aa Pa: ( ~5~ an >:~-~e-oar .z~M•~ Cs~ ew'~ B/e~ p j ~~~ P P,,~~SG~e ~ro~w 6 SU 4 ro soo pr% o~ 1- 5-0~ i P ~ a 3 ~ ~ i i y y ~: ! ~ ~ { t } tt ' y { i ~ ~d ;i E 1 ~ ~~ ~ ? ~ ~ ~ ~ j ~ ~ t ~ A t ~ +{, ~,~} ~til ~i ! , 3 , ~ ~.- 4 ! ( ~i ~ !r;q ¢: : '. `._ !~. •i •i t/IS/2008 4:50:98 VM t:\OoCUmentS and Setttngs\g7v\DeSktop\" d TrendsiBC #21n' Well.aaTrend ~~ /b-47 f-ea !-/5 -4$~ J~6-~ r~ A.197 pxt (22 alerv~y, 44'.+~Q".+SEi) ~I~~ ~,1r - ~,x (~; ~~ 167-Q~, ~Z ~ vl H e ~^ G'ct s ~ a''~ q~ pry s s u r G- .Z t-- C, r ~e d~' t ~ ~ ,r~'-t .^ a~ .1 BC #2 In) Weil ? 2-/7-D7 (12/17?Z?)071:EW:26 ?~M j 474 ps+ 582 vst (4 days, t+RzSd:26j • ~, sg ou 1 p~ ~ rbg p,-~ s ~ ~<-~ aecz_wer_ ,. ~~ w~ 2 Snx~ian Castr, tmx P~ kgtrs94v,. ~ c~ 400 1400 11k+~-~tvt~wi~e~+.., o:aa:on.... p a, aac-zyni_... ac wea z m castq ~uaK P~ Rd~s9+~ .. cs+ a.oraao ~oo.oo.., tU•~iv~wna9n.. n:ao:oo... [Jfw,,,APC?_W91_... BCtvea2lnkntbn7ubki0Pe1 kgfn9i4.., psi t00 1900 1lkgfpy~s•11VjEWltggi,.. 0:00:00.,.. 1/15/2008 5:18:52 PM C:1Documents and Setiings\9lvii~esklnpiSaved Trends\BC #2 Ind Well 1-15-08 Mff.aaTrend kgfnt444-2arv.k~F.nrotmm•.A9Q Wdl 2_tnnd v*(tvetcj ~~~- C2°~ l~ (.("~f ~f-Z ~(~7-cam Z[~ ~rr~„r G~-s'"~ ~ZpK~Kre. /,r/~~ tt: 157.'CQ83:29:3E PV.)3)9^a psi ~~% (1f25f20tS84;zt:t1's PM) 1778 ps# ~.;i' 1904 '.~hh~'~ G0.S~"~ •91 2Cll.fGaOt Du~ ~'' r.aacu ray --~ ~'" Io ~~45~~ ~~ BC #2 Ind (Nell CI ~ ~ Tbg~ ~~q~ Ps, ,„„fM ,,~ ~ •26 Dst (0 daaa, ~9:5t:2b) ._______....w_.~/.._.._.- ~ ~~_ _.~'• _ _ f f /~ ~ ,~ ~. Gs9 ~~~....~ tro pressur~~~ 1~a~ ~ 1~ IYI=T • ~~. S~''~ IK3 ~~' `~~ i i 2:22:5 PM 2:s6:+'S PM kJ 19}2GG8 2:15 "2408 a8r2_Wel_, .. EC We12 Inpttan Casfnp Irrru Psi kgfrs9~9. . RBC2_Wd_ ., BC WTI 2 trr}~xtbn Cesrg gtder Ps, r1/rs919 .. AtJ~2 WeN_ .. TSC WeM 21n1ectMm T,.AiYq Psw Mpfrs449. 3:i+JoiS iT7 ~ r3~:ro rm iJIS/2008 ~,~n.~~ •~~ ;{t5j2008 ili51200t ~{~4r,po9 aaw_k0~.msc.rrsm•nbt~°.,y"~~, "' ;rvge+_~""CCvrt+c,! .__. 'okx Ek1N5 NArtY1NxA Ma~rYrxrrn IOAdd'ess TMro+Olfsetl _ ps, +~ t906 114gfovrs-t1YlfWir+~gn... 0:00:00.... psf 0.00000 100.00... Ilkgfpws•t1Ytl:Witegn.. 0,00:00.... psi t00 1400 11kpf0YK-7tVliWltapn,,, 0:00:00..., 4;31;2Q PM nts and Settings197v\ReSkkop\`+~+~ TrendslBC #2 InJ WeM.aaTrend r :i5 Pnt 1725x`2908 3 r: , . . (. Nt,. ') Marathon MARATHON Oil Company Marathon Oil Company Alaska Asset Team P.O. Box 1949 Kenai, AK 99611 Telephone 907/283-1326 Fax 907/283-1350 August 16, 2007 RECEIVED AUG 2 0 Z007 Mr. Tom Maunder Alaska Oil & Gas Conservation Commission 333 W yth Ave Anchorage, Alaska 99501 Reference: 10-404 Sundry Report Field: Beaver Creek Field Well: BC-2 Alaska Oil & Gas Cons. Commission Anchorage \~1- o'.}50 Dear Mr. Maunder: Attached and submitted for your records is the Sundry Form 10-404 pertaining to the acid stimulation completed on BC-2 (water Disposal Well). Also attached is the Operations Summary and current wellbore diagram. If you have any questions or need further information please call me at (907) 398-9954. Sincerely, ~~0 Senior Production Engineer SCA.~NED AU G 2 1 2007 Enclosures: 10-404 Sundry Report Well Schematic Operations Summary cc: Houston Well File Kenai Well File KJS MAM , . STATE OF ALASKA . ~ RECEIVED A~KA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS AUG 2 0 2007 ,J lIr"..,... n;, n ... 1 . Operations Abandon U RepairWell U Plug Perforations U Stimulate ~ OtherV" UQ;) vUJlS. I.,Ommlss Performed: Alter Casing D Pull Tubing D Perforate New Pool D Waiver D Time Extension D Ancnorage Change Approved Program D Operat. Shutdown D Perforate D Re-enter Suspended Well D 2. Operator 4. Well Class Before Work: 5. Permit to Drill Number: Name: Marathon Oil Company Development D ExploratoryD 167-026 (' 3. Address: Stratigraphic D Service [;2] 6. API Number: PO Box 1949, Kenai Alaska, 99611-1949 50-133-20021-00-00 ;' 7. KB Elevation (ft): 9. Well Name and Number: 155' (15' AGL) / Beaver Creek # 2 / 8. Property Designation: 10. Field/Pool(s): FEDA 028118 Beaver Creek I Sterling / 11. Present Well Condition Summary: Total Depth measured 15,697' / feet Plugs (measured) 5,197' true vertical 15,697' feet Junk (measured) 0 Effective Depth measured 5,197' feet true vertical 7,890' feet Casing Length Size MD TVD Burst Collapse Structural 265' 20" 280' 280' NA NA Conductor 0 0 0 0 0 0 Surface 2,196' 13-3/8" 2,211' 2,211' 3,450' 1,950' Intermediate 8,820' 9-5/8" 8,835' 8,835' 6,330' 3,810' Production 10,171' 7" 15,439' 15,439' 8,160' 7,020' Liner 258' 5" 15,697' 15,697' 10,140' 0 Perforation depth: Measured depth: 5,007' . 5,220' True Vertical depth: 5,007' . 5,220' Tubing: (size, grade, and measured depth) 3-1/2" N - 80 4,961' Packers and SSSV (type and measured depth) Baker FH Packer 4,961' 12. Stimulation or cement squeeze summary: Acid stimulation Intervals treated (measured): Sterling B1, B2, and B3 sands from 5,007' to 5,197' MD. Treatment descriptions including volumes used and final pressure: 23.8 bbls of lead One Shot Acid @ 50% Xylene and 50% HCL (7.5% concentrate) followed with 47.6 bbls of 1/3 strength mud acid (4% HCL 11% HF acid). Final pressure = 2,300. 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: NA NA 575 BPD 60 2,300 Subsequent to operation: NA NA . 575 BPD 100 1,900 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run NA Exploratory D Development D Service 0 Daily Report of Well Operations NA 16. Well Status after work: OilD Gas D WAG D GINJ D WINJ D WDSPL 0 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. I Sundry Number or N/A if C.O. Exempt: 307- 018 Contact Kevin Skiba (907) 283-1371 Printed Name Michael A. Mullin Title Senior Production Engineer Signature ~~;j/-1'''¡L'/~- Phone (907) 283-1337 Date 8116/2007 { on Form 1 0-404 Revised 04/2006 0 R , (ì I N ~4 I RBDMS 8FL AUG 2 1 2007 ~f.). , Submit Original O~ ~ . . Marathon Oil Company Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: SEAVER CREEK 2 SEAVER CREEK 2 MAINTENANCE/REPAIR Date I I I Sub i From - To i Hours Code! Code Phase I 08:00 - 09:30 1.50 SAFETY! MTG_ CMPSTM 1/11/2007 09:30 - 13:50 4.33 RURD_iACID I 2.17 RURDjACID 3.00 PUMP J ACID I I I I I I I CMPSTM CMPSTM 13:50 - 16:00 CMPSTM 16:00 - 19:00 19:00 - 20:00 I i I I 1.00 RURD_IACID Started field injection pumps to displace treatment. CMPSTM RDMO BJ Services. No spills or incidents. Field injection pressure dropped from 2300 psi to 1900 psi during injection cycle. Page 1 of 1 S~rt: 1~1~007 Rig Release: Rig Number: Spud Date: 7/13/1967 End: Group: Description of Operations Held PJSM with all MOC, ASRC, and BJ personnel to discuss MSDS, PPE, mitigation plans, and operational plan relative to pumping HCL and HF acid. Started and warmed up fluid pumper. Spotted ASRC vac truck. Pressure testede lines to 6000 psi. Start injection with water. Unable to maintain prime on acid. Suction manifold frozen. Cover and thaw manifold. Vacuum dry all lines. Pumped 1000 gals. of 7-1/2% HCL / 50% Xylene acid at 0.7 BPM with pressure increasing to 2130 psi. Pumped 2000 gals 4% HCU 1 % HF acid at 1 BPM and 2300 psi throughout. Flushed all surface lines and pumps with 10 Bbls water and injected at 2300 psi. Printed: 8/15/2007 4:36:37 PM 2 2 (I 5007'~5028' Fill @5132'SLM(11/11/01) 5125'~5140' 5155'~5220' Isolated: liner stub 5268' DMT ov, Cement @5197' Cement Retainer@ 5221' 95/8" 8rd Lease AK Last Revision Date: ® ~r. ro ffiì ~A r¡m~ If % ~ l ~ llJ If ~ lL,/ru QÙ [,0,h AI,ASIiA OIL A1Q) GAS CONSBRVATlON COMMISSION SARAH PALIN, GOVERNOR 333 W. 7th AVENUE. SUITE 100 ANCHORAGE. ALASKA 99501-3539 PHONE (907) 279·1433 FAX (907) 276-7542 Michael Mullin Sr. Production Engineer Marathon Oil Company PO Box 1949 Kenai, AK 99611-1949 SCANNED JAN 1 7 2007 Re: Beaver Creek Field, Sterling Undefined Disposal Pool, Beaver Creek #2 Sundry Number: 307-018 Dear Mr. Mullin: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Sup~rior Court unless rehearing has been requested. Sincerely, DATED this May of January, 2007 Enel. !(P't-ú'd0 (. ~) Marathon MARATHON Oil Company Marathon Oil Company Alaska Asset Team P.O. Box 1949 Kenai, AK 99611 Telephone 907/283-1326 Fax 907/283-1350 January 5,2007 RECE\VED JAN 1 1 Z007 ~aska' Ó¡I & Gas Cons. Commission Anchorage Mr. Tom Maunder Alaska Oil & Gas Conservation Commission 333 W ¡th Ave Anchorage, Alaska 99501 Reference: 10-403 Sundry Notice Field: Beaver Creek Field Well: BC-2 Dear Mr. Maunder: Attached and submitted for your approval is the Form 10-403 to acidize the open Sterling perforation intervals in the Beaver Creek #2 water disposal wellbore. A mud acid treatment was pumped into this well in Sept. 2004 reducing the injection pressure at 1 BPM from 2275 psi to 2000 psi. Current injection pressure is 2200 psi at 0.4 BPM. It is proposed to retreat the perforated intervals with a small acid stimulation. Also attached for your records is the well schematic and proposed operational procedure. If you would like any other information, please contact me at 283-1337 or mmullin@marathonoil.com. . Since:~ ~.. " --¿;;U-P!'~þ( MiCh~ MUIli? ¿<- Senior Production Engineer Enclosures: 10-403 Sundry Notice Well Schematic Operations Procedure cc: AOGCC Houston Well File Kenai Well File KJS Abandon 0 Alter casing 0 Change approved program 0 2. Operator Name: Marathon Oil Com an PO Box 1949, Kenai Alaska, 99611-1949 7. If perforating, closest approach in pool(s) opened by this operation to nearest property line where ownership or landownership changes: Spacing Exception Required? Yes 0 9. Property Designation: 13. Attachments: Description Summary of Proposal 0 Detailed Operations Program 0 BOP Sketch 0 15. Estimated Date for 17. Verbal Approval: Date: 1/4/2007 Commission Representative: Thomas Maunder Æfl"f'V./1 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Printed Name Michael A. Mullin Title Senior Production Engneer 1. Type of Request: 3. Address: 12. Total Depth MD (ft): 15,697' Casing Structural Conductor Surface Production Liner Liner Perforation Depth MD (ft): 5007'- 5220' Packers and SSSV Type: Commencing Operations: P· 101 STATE OF ALASKA -ftf;{;,;;> RECE IVED 1l^ U I t~ ALASKA OIL AND GAS CONSERVATION COMMISSION Þl .IAN 1 1 2007 YVI} APPLICATION FOR SUNDRY APPROVALS l"J 20 AAC 25.280 Alaska Operational shutdown 0 Perforate 0 Waiver []nch . Plug Perforations 0 Stimulate 0 Time Extension Û orage Perforate New Pool 0 Re-enter Suspended Well 0 4. Current W,ell C~ 5. Permit to Drill Number: Developm~,.w Exploratory 0 167-026/ Stratigraphic ~ ,(,' Service 6. API Number: \J.-- 50-133-200211 Suspend 0 Repair well 0 Pull Tubing 0 n 8. Well Name and Number: FEDA028118 ¡ No 0 1J. KB Elevation (ft): 11. Field/Pool(s): 155' KB (15' AGL) PRESENT WELL CONDITION SUMMARY Effective Depth MD (ft): Effective Depth TVD (ft): 5,197' 7,890' Plugs (measured): 5,197' Burst N/A Collapse N/A Beaver Creek #2 ¡ v ~G..~ Beaver Creek / Sterling ( ~\: ~ Junk (measured): Total Depth TVD (ft): 15,697' Length 265' Size MD 280' TVD 280' 20" 2,196' 8,820' 10,171' 258' 2,211' 8,835' 15,439' 15,697' Tubing Grade: N-80 3,450 1,950 6,330 3,810 8,160 7,020 10,140 702,010,490 Tubing MD (ft): 4,961' 13-3/8" 9-5/8" 2,211' 8,835' 15,439' 15,697' Tubing Size: 3-1/2" 7" 5" Perforation Depth TVD (ft): 5007'- 5220' Packers and SSSV MD (ft): Baker FH Packer 4,961' ~ 1/9/2007 Exploratory 0 16. Well Status after proposed work: Oil 0 Gas 0 WAG 0 GINJ 0 Plugged WINJ o o Abandoned 0 WDSPL 0 Michael A. Mullin Signature ~~dphone (907) 283-1350 COMMISSION USE ONLY Date Sundry Number: :3() Conditions of approval: Notify Commission so that a representative may witness Plug Integrity 0 Other: BOP Test 0 Location Clearance 0 Mechanical Integrity Test 0 RBDMS 8Ft JAN 1 2007 Subsequent Form Required: L\~ '-\ Approved by: APPROVED BY THE COMMISSION Date: /-/1, --Or- Submit in Duplicate Form 10-403 Revised 06/2006 Beaver Creek Field Pad 2 BC2 (Injection Well) rev. 11/5/01 4889' Otis XA circ sleeve 4923' Baker PH hyd pkr Perforations: Sterling B-1: 5007'-5028' 5032'-5052' FíII @ 5132' SLM (11/11/01) Sterling 8-2: 5125'-5140' Sterling 8-3: 5155'-5220' Sterling B-3a: 5230'-5244' squeezed 8-3a:5263'-5265' Sterling 8-4: 5324'-5344' 7" liner stub 5268' 7" liner shoe @ 15,439' 5" liner shoe @ 15,697' ngle/Perfs BHP: 0 FWHP: Date Completed: Prepared By: 20" 94# H-40 @ 280' 12 3/8" 72# & 68# N-80 J-55 @ 2211' Production Tubing: 3 1/2" 9.2ppf Butt, N-80 4961' Baker WL entry guide Cement Cap@519T Cement Retainer @ 5221' 9 5/8" 43.5# N-80 8rd @ 8835' o 0 FBHT: Other: RKB: Last Revision Date: 11/5/01 " Marathon Oil Company Alaska Region Beaver Creek #2 Water Disposal Well Beaver Creek Field, Pad 2 Mud Acid Clean out History: Produced water from BC field is injected into Sterling B-1, B-2, and B-3 benches. A coil tubing cleanout performed on 9/1 0/04 removed fill across the Sterling B-3 perforations from 5150' to the cement plug top at 5197' MD. A mud acid stimulation was performed in Sept 2004 with a reduction in injection pressure of250 psi. The injection pressure has increased back to pre mud acid levels in the last 2 years. The wellbore is constructed with 3 W', 9.2 ppftubing in 9-5/8" casing. The tubing tail is at 4961' and minimum ID is 2.75". There is an Otis XL Ball Valve Nipple at 483' KB and an Otis XA Circ Sleeve at 4889'. The difference between GL and KB is 15'. Objective: Acidize the Sterling Bl through B3 perforations with mud acid to reduce wellhead injection pressure. Procedure: 1. Spot liner on location as needed. Lay liner and berm under BJ Services acid transport and pump lines. Call out vac truck to supply filtered produced water to BJ Services pump to pressure test BJ Services pump lines and displace acid treatment down the production tubing. 2. MIRV BJ Services acid transport and enclosed fluid pump. NOTE: Tree flange connection is 4-1116", 10K. Hold PJSM to discuss potential hazards and operational plan. Review MSDS sheets of all chemicals present and have appropriate PPE donned. Ensure pressurized eye wash container and Calcium Gluconate neutralizing kit for HF acid is on location. 3. MU pump lines ensuring that drip pans are placed under all connections. Record and report annulus pressure, injection rate, and injection pressure prior to beginning pumping operations. 4. Pressure test BJ Services pump lines to 4000 psi with produced water. Maximum surface pressure not to exceed 2900 psi during acidizing operations. " ~ , Page 2 of2 5. Commence pumping (bullhead) acid treatment as follows monitoring pressure and rates: a. 1500 gals. 7.5% HCL acid with 50% Xylene @ 2 BPM b. 1500 gals. 4% HCL and 1.% HF acid with additives @ 2 BPM c. 70 bbls. 2% KCI water flush at 1 BPM. 6. RDMO BJ Services acid pumping equipment. Reinitiate produced water injection through BC facilities. Closely monitor rates, volumes, and surface injection pressures. 7. Please call Mickey Mullin at 398-9954 or 283-1337 with questions and results. Beaver Creek #2 Sterling Acid Procedure KDW - 1/8/2007 7:07:36 AM Beaver Creek Pad 2 BC2 (Injection Well) rev, 11/5/01 4889' Otis XA circ sleeve 4923' Baker FH hyd pkr Perforations: Sterling B-1: 5007'-5028' 5032'-5052' Fill @ 5132' SLM (11/11/01) Sterling B~2: 5125'-5140' Sterling B-3: 5155'-5220' Sterling B-3a: 5230'-5244' squeezed B-3a: 5263'-5265' Sterling B-4: 5324'"5344' 7" liner stub 5268' 7" liner shoe @ 15,439' 5" liner shoe @ 15,697' 20" 94# H-40 @ 280' 12 3/8" 72# & 68# N-80 J-55 @ 2211' Production Tubing: 3 1/2" 9.2ppf Butt, N-80 4961' Baker WL entry guide Cement Cap @5197' Cement Retainer @ 5221' 9 5/8" 43.5# N-80 8rd @ 8835' Well Name & Number: Seaver Creek#2 Lease I Beaver Creek Unit, Pad 2 County or Parish: Kenai Penn Borough I State/Provo AK Country: I USA Class II Dísposal Well I Angle/Perfs Angle @KOP¡md Pepth I 0 I KOP TVD I 0 BHP: 0 BHT: 01 Completion Fluid: I FWHP: FBHP: I FWHT: I FBHT: I Other: Date Completed: RKB: Prepared By: DMT I Last Revision Date: 11/5/01 I Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date 9/4/2004 9/9/2004 9/10/2004 Marathon Oil Company Operations Summary Report SEAVER CREEK 2 SEAVER CREEK 2 MAINTENANCE/REPAIR Start: 9/4/2004 Rig Release: Rig Number: Spud Date: 7/13/1967 End: Group: Sub Code Code Phase Description of Operations 07:00 - 08:00 From - To Hours 08:00 - 11 :30 11 :00 - 16:00 16:00 - 18:30 07:00 - 10:00 10:00 - 10:45 10:45 - 11 :00 11 :00 - 11 :50 11 :50 - 12:30 12:30 - 15:30 15:30 - 17:00 1.00 RURD_ SLlK WBPREP MIRU wire line unit. Hold PJSM and uptain work permit. Discussed procedure prior to rigging up on well. Water injection pumps shut down while conducting wire line work on well. 3.50 TAG_ BOTM WBPREP PU well house to get lubricator over well. Whp at tree+ 2350 psig. RIH with a 2.5" bailer. Tagged fill at 5130' WLM, 5150' KBD. POOH with sample. OOH with sample. GOOD sample. RD. Move to pad 3. 5.00 RURD_ COIL CLNOUT MI RU CT. Set flow back tank and supply tank at tree. Held PJSM when CT arrived on location. Had to wate till crane released on BC 14 KCL mixing operations. Continue with rigging up the coil. While rigging up BOP's swab valve leaking, one of the hands shut master valve cause pressure up on injection flow line. High pressure contol shut down the pump. Cautioned BJ hands about closing in valves. Continue with rigging up flow back iron for clean out tomorrow 2.50 TEST _ EQIP CLNOUT PTflow back iron and BOP's. Low test at 200 psig/ high at 4500 psig. test good. Lay down grease injector. Secured well with night cap. turned will back over to prodution. BJ left lease. 3.00 RUNPU COIL CLNOUT BJ on lease. Held PJSM discussed work scope with operations. Uptained work permit. Continuation from previous days RU on location. Pickup the injector head and stab on well. Made shell test at 200 psig low and 4500 psig. Had MaC operator shut down pump and lock out. Open well, RIH with 1.5" coil. BHA consist of 2.5" dimple connector, 11 1/4" dubble flapper check, & nozzle with 6 ea. 3/16" ports 5" long, 1 3/4" OD. Returns to tank while running in well. H20 Clear. 0.75 TRIP _ TOOL CLNOUT When coil at 500' chain sprocket skipping, on coil real. Shut down to correct problem. Continue RIH with coil. CT at 5100' WHP= 52 psig, pumping minium rate at 0.30 BPM while RIH with coil. Increased PIR to 2.0 BPM. 0.25 WASH FILL CLNOUT Coil start washing fill at 5110' CTM. Injection rate to 2.0 BPM. PIP= 3200 psig. Continue down hole. 0.83 WASH FILL CLNOUT Work nozzle down to 5150' CTM, PIP= 3231 psig, WHP = 52 psig. Good returns to tank. Check PIR to returns. Washing with no progress. Sat on top of hard fill for 35 minutes no progress. PUH with coil to 5130', RBIH to 5150' CTM coil sat down, stacked 1000 Ibs on nozzle. Could not pump off fill. PU coil to tubing tail to do rate injection test. When coil in tubing open up back side of coil and shut in choke to flow back tank. 0.67 WASH FILL CLNOUT CT at 4931' CTM. Start PIR at 1.0 BPM. PIP= 1680 psig. After 10 BBLs pumped PIP= 2277 psig, WHP= 2335 psig. Increase PIR to 2.0 BPM, PIP=2479 psig, WHP= 2500 psig after 11 BBLs pumped PIP= 2601 psig, WHP= 2585 psig Increase PIR to 3.0 BPM, PIP= 2605 psig, WHP= 2580 psig after 40 BBLs pumped PIP= 2680 psig, WHP= 2800 psig. return fluid clear to flow back tank. 3.00 TRIP _ TOOL CLNOUT RIH with Coil after injection test to tag fill at 5150' CTM. Ddiscussed options on cleaning out fill to PTD. Decided to POOH with coil. 1.50 RURD_ COIL CLNOUT OOH with coil secure well and contiue with RD. Had vac truck pull water out of flow back line, pump and hoses. BJ continue with RD. Printed: 1/4/2007 3:13:59 PM ~ . . Marathon· Oil Company: . Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: BEAVER CREEK 2 BEAVER CREEK 2 MAINTENANCE/REPAIR Start: 9/4/2004 Rig Release: Rig Number: Spud Date: 7/13/1967 End: Group: . Sub Code 9/10/2004 15:30 - 17:00 1.50 RURD_ COIL CLNOUT Vac truck set up to pull water out of flow back tank to use on BC 14. 11 :00 - 13:30 Flow back tank had 260 bbls in tank Suplly tank has 170 BBLS clean KCL water. Spotted BJ Services Acid Transport on bermed liner and tied into BJ fluid pumper. Held PJSM with all MOC, Veco, and BJ personnel to discuss MSDS, PPE, mitigation plans, and operational plan relative to pumping HCL and HF acid. Started and warmed up fluid pumper. Spotted Veco vac trucks (one with produced water to pressure test and flush acid and one with fresh water to provide dilution if personnel soaked with acid). Finished berming liner. Made final inspection of piping and valves. 1.00 RURD_ ACID CLNOUT Changed out leaking BJ pump line fitting after failed attempt to treating line with produced water. Pressure tested line to wellhead to 4000 psi. Opened master valves noting 1020 psi WHP. 2.50 PUMP _ ACID CLNOUT Pumped 1000 gals. of 7-1/2% HCL acid at 1 BPM with pressure increasing to 2350 psi. 9/23/2004 07:30 - 08:00 0.50 RURD - STIM CLNOUT 08:00 - 09:00 1.00 SAFETY MTG_ CLNOUT 09:00 - 10:00 1.00 RURD - ACID CLNOUT 10:00 - 11 :00 Pumped 2000 gals 6% HCU1.5% HF acid at 1 BPM and 2430 psi throughout. Once the HCUHF acid reached the top perf at 5007', the treating pressure decreased steadily from 2430 to 1930 psi. Pumped 1000 gals 7-1/2% HCL acid at 1 BPM with treating pressure increasing from 1930 to 2050 psi. 13:30 - 14:30 Flushed acid with 80 bbls filtered produced water. The first 50 bbls of displacement was pumped at 1 BPM and 2000 psi. The next 20 bbls pumped at 2 BPM and 2350 psi. The last 10 bbls pumped at 3 BPM and 2400 psi. Shut down pumps. 1.00 RURD_ ACID CLNOUT RDMO BJ Services. No spills or incidents. Printed: 1/4/2007 3:13:59 PM M Marathon MARATHON Oil Company January 4, 2007 Mr. Tom Maunder Alaska Oil & Gas Conservation Commission 333 W 7th Ave Anchorage, Alaska 99501 Reference: 10-404 Sundry Report Field: Beaver Creek Field Well: BC -2 Dear Mr. Maunder: Marathon Oil Company Alaska Asset Team P.O. Box 1949 Kenai, AK 99611 Telephone 907/283-1326 Fax 907/283-1350 seMNED JAN 17 2007 The acid stimulation work approved in September 2004 on BC -2 (water Disposal Well) was completed in September 2004. 1 have not found the 10-404 Sundry report from this work. Attached is the 10-404 Sundry Report, Operations Summary, and wellbore diagram. I apologize for this report not being filed and we are making every attempt to eliminate missing reports in the future. If you have any questions or need further information please call me at (907) 398-9954. Sincerely, Mi hael A. ullin Senior Production Engineer Enclosures: 10-404 Sundry Report Well Schematic Operations Summary cc: Houston Well File Kenai Well File KJS STATE OF ALASKA $ ALASKA OIL AND GAS CONSERVATION COMMISSION p/ $ REPORT OF SUNDRY WELL OPERATIONS JAN 1 l 2007 1. Operations Abandon Repair Well Plug Perforations LJ Stimulate L�✓J 418WO, Performed: Alter Casing ❑ Pull Tubing ❑ Perforate New Pool ❑ `►b-i9ftfl9lSSl Waiver ❑ Time Extension Change Approved Program ❑ Operat. Shutdown ❑ Perforate ❑ Re-enter Suspended Well ❑ +~nchorage 2. Operator Marathon Oil Company 4. Well Class Before Work: 5. Permit to Drill Number: Name: Development Q Stratigraphic❑ Exploratory Service❑ 167-026 3. Address: 6. API Number: PO Box 1949, Kenai Alaska, 99611-1949 50-133-20021 7. KB Elevation (ft): 9. Well Name and Number: 155' KB 15' AG L) Beaver Creek #2 8. Property Designation: 10. Field/Pool(s): FEDA028118 Beaver Creek / Sterling 6v 11. Present Well Condition Summary: Total Depth measured 15,697' " feet Plugs (measured) 5,197' true vertical 15,697' feet Junk (measured) Effective Depth measured 5,197' feet true vertical 7,890' feet Casing Length Size MD TVD Burst Collapse Structural 265' 20" 280' 280' N/A N/A Conductor Surface 2,196' 13-3/8" 2,211' 2,211' Intermediate 8,820' 9-5/8" 8,835' 8,835' Production 10,171' 7" 15,439' 15,439' Liner 258' 5" 15,697' 15,697' Perforation depth: Measured depth: 5007'- 5220' True Vertical depth: 5007'- 5220' Tubing: (size, grade, and measured depth) 3-1/2" N-80 4,961' Packers and SSSV (type and measured depth) []Baker FH Packer 114,961' 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: Injection 1.0 2275 Subsequent to operation: 1 2000 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run Exploratory❑ Development ❑ Service Q Daily Report of Well Operations X 16. Well Status after work: Oil ❑ Gas ❑ WAG ❑ GINJ ❑ WINJ ❑ WDSPL ❑✓ 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: / ��/1 41-102 Contact Michael A. Mullin Printed Name Michael A. Mullin Title Advanced Production Engneer Signature Phone ❑(907) 283-1350 Date f Form 10-404 Revised 04/2006' / '� ��Submit Original Only RE: Verbal permission for BC-2 (167-026) stimulation . . Thank you Tom, We have completed the prior 404 and will include ìt tomorrow wìth the new 403. Mìckey From: Thomas Maunder [mailto:tom_maunder@admin.state.ak.us] Sent: Thursday, January 04, 2007 2:20 PM To: Mullin, Mickey Cc: Skiba, Kevin J. Subject: Re: Verbal permission for 6(-2 (167-026) stimulation Mickey, Following your call, I have looked at the well file. The operation you are proposing is similar to the one proposed in September 2004. One thing I note is that Marathon does not appear to have filed the 404 Report of Sundry Operations for the September 2004 stimulation. The last entry in our file is the MIT that was performed in May 2006. You have verbal approval to proceed with the stimulation. We will look forward to receiving the 403. Call or message with any questions. Tom Maunder, PE AOGCC Mullin, Mickey wrote, On 1/4/2007 1 :28 PM: ItANNED JAN 0 8 2007 Tom, ~', ",." .' I need verbal approval to acidize the open Sterling perforation intervals in the Beaver Creek #2 water disposal wellbore. A mud acid treatment was pumped into this well in Sept. 2004 reducing the injection pressure at 1 BPM from 2275 psi to 2000 psi. Current injection pressure is 2200 psi at 0.4 BPM. It is proposed to retreat the perforated intervals with a small acid stimulation. Last weekend we attempted to acidize BC-3 and were unable to inject all of the acid. My timing for this job is dictated by needing to utilize the remaining acid from this job. Original plans were to stimulate the well in the spring. Thank you for your assistance. We will submit a 10-403 sundry notice tomorrow. Mickey Mullin Senior Production Engineer Marathon Oil Company (907) 283-1337 1 Of/1.lr~ dY1 Yy;- 1/8/20078:41 AM MEMORANDUM e State of Alaska e Alaska Oil and Gas Conservation Commission TO: Jim Regg P.I. Supervisor .---, I '.'/ .(/ ä; I ¡y.p ì...; Z~( "-í f DATE: Thursday, May 25,2006 SUBJECT: Mechanical Integrity Tests MARATHON OIL CO 2 SEAVER CK UNIT 2 Src: Inspector ~ \'oyO Reviewed By: .--r17 iZ-- P.I. Suprv. ! of Comm FROM: JeffJones Petroleum Inspector Well Name: BEAVER CK UNIT 2 API Well Number 50-133-20021-00-00 Inspector Name: Jeff Jones Insp Num: mitlJ060524154030 Permit Number: 167-026-0 Inspection Date: 5/18/2006 Rei Insp Num Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well ! 2 ¡Type Inj. : N !TVD 4923 ! IA ! 980 1750 1750 I 1750 I j 10Al ! I P.T. I 1670260 iTypeTest: SPT I Test psi 1500 0 0 0 0 i í , OA : I i Interval 4YRTST P/F P TUbi~ÓOO 900 800 800 ! i 1- i Notes 0.3 bbls 50/50 methanol pumped. NON-CONFIDENTIAL ,nt" .~1\\~FÜ ~~~{J ~..~ .".., ~~' ...., r "','_ ;TJ, Thursday, May 25, 2006 Page 1 of 1 ~1r~1rŒ (ill~ ~~~~æ~ / AI.Mi1iA. ORAND GAS / CONSERVATION COMMISSION / j FRANK H. MURKOWSKI, GOVERNOR 333 W. 7'" AVENUE. SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Ken D. Walsh Advanced Production Engineer Marathon Oil Company P.O. Box 1949 Kenai, AK 99611-1949 ìb1-0~ Re: Beaver Creek #2 Sundry Number: 304-354 Dear Mr. Walsh: Enclosed is the approved Application for Sundry Approval relating to the above- referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. BY ORDER OF THE COMMISSION DATED this~ day of September, 2004 Enc!. Alaska Business Unit Marathon Oil Company P.O. Box 1949 Kenai, AK 99611-1949 Telephone 907/283-1311 Fax 907/283-6175 September 17, 2004 Winton Aubert AOGCC 333 West 7th Ave Suite 100 Anchorage, AK 99501 Dear Mr. Aubert: Attached and submitted for your approval is the Form 10-403 to acidize the open Sterling perforation intervals in the Beaver Creek #2 water disposal well bore. A coil tubing cleanout to remove fill over the Sterling B-3 perforations in September 2004 did not substantially lower the wellhead injection pressure. A mud acid treatment has been pumped into this well numerous times in the past with good results. It is proposed to retreat the perforated intervals with a small acid stimulation. Also attached for your records is the well schematic and proposed operational procedure. If you would like any other information, please contact me at 283-1311 or ~h@marathonoil.com. Sincerely, ,~'t.lJ~ Ken D. Walsh Advanced Production Engineer Enclosures RECEIVED SEP 2 0 2004 Alaska Oil & Gas Cons. Commission Anchorage OR\G\NAL V-J61r q fl.' { 2.0°4 1. Type of Request: Abandon U Suspend D Operational shutdown U Perforate LJ Waiver U Annular Dispos. U Alter casing D Repair well 0 Plug Perforations 0 Stimulate 0 Time Extension 0 Other 0 Change approved program 0 Pull Tubing 0 Perforate New Pool 0 Re-enter Suspended Well 0 2. Operator Name: 4. Current Well Class: \J-l6A- 5. Permit to Drill Number: MARATHON OIL COMPANY Development -EJ Exploratory 0 167-026 ./ 3. Address: Stratigraphic 0 Service M 6. API Number: P. O. Box 1949, Kenai, AK 99611-1949 50-133-20021 / 7. KB Elevation (ft): 9. Well Name and Number: 155' KB (15' AGL) Beaver Creek #2 / 8. Property Designation: 10. Field/Pools(s): FEDA028118 Beaver Creek/Sterling 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 15,697' 15,697' 5,197' 7890' 5,197' Casing Length Size MD TVD Burst Collapse Structural 265' 20" 280' 280' N/A N/A Conductor Surface 2,196' 13 3/8" 2,211' 2,211' 3450 1950 Production 8,820' 95/8" 8835' 8835' 6330 3810 Liner 10,171' 7" 15,439' 15,439' 8160 7020 Liner 258' 5" 15,697' 15,697' 10140 10490 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 5007 -5028'/5032.5052' 5007-5028'/5032-5052' 3-1/2" N-80 4961' 5125.5140'/5155-5220' 5125-5140'/5155-5220' Packers and SSSV Type: Packers and SSSV MD (ft): Baker FH Packer 4923' 12. Attachments: Description Summary of Proposal U 13. Well Class after proposed work: \fiG1\- Detailed Operations Program 0 BOP Sketch 0 Exploratory 0 Development -B- Service ~ 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: 9/20/2004 Oil 0 Gas 0 Plugged 0 Abandoned 0 16. Verbal Approval: Date: q I ¡clz.oo4- WAG 0 GINJ 0 WINJ 0 WDSPL 0 Commission Representative: W. 1\ u.b €.r t- 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Ken D. Walsh Printed Name Ken D. W~ Title Advanced Production Engineer Signature '(l~~, Phone 907-283-1311 Date 9/1712004 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: JOe¡.. 35'Ý Plug Integrity 0 BOP Test 0 Mechanical Integrity Test 0 Location Clearance D RECEIVED Other: RBDMS SF l SEP 2 1 70n4 SEP 2 0 2004 S"""'",W ; 0 ¥4-. OR\G\~1 ~L Alaska Oil & Gas Cons, Commission Anchorage Date fL.'; IIJ BY ORDER OF V Approved by. ~ """. ,~IC',Ç2MMISSI0~~IR ._. .____THE COMMISSION <=~~~ I n ~ ..~~~~ \J '-' f STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVAL 20 AAC 25.280 ~ Beaver Creek Field Pad 2 BC2 (Injection Well) rev. 11/5/01 4889' Otis XA circ sleeve 4923' Baker FH hyd pkr Fill @5132'SLM(11/11/01) Perforations: Sterling B-1: 5007'-5028' 5032'-5052' Sterling B-2: 5125'-5140' Sterling B-3: 5155'-5220' Sterling B-3a: 5230'-5244' squeezed B-3a: 5263'-5265' Sterling B-4: 5324'-5344' 7" liner stub 5268' 7" liner shoe @ 15,439' 5" liner shoe @ 15,697' 20" 94# H-40 @ 280' 13 3/8" 72# & 68# N-80 J-55 @ 2211' Production Tubing: 3 1/2" 9.2ppf Butt, N-80 4961' Baker WL entry guide Cement Cap @5197' Cement Retainer @ 5221' 95/8" 8rd 43.5# N-80 @ 8835' Marathon Oil Company Alaska Region Beaver Creek #2 Water Disposal Well Beaver Creek Field, Pad 2 Mud Acid Cleanout WBS # WO.O4.10959.EXP History: Produced water from BC field is injected into Sterling B-1, B-2, and B-3 benches. Injection pressure has increased 250 psi (from 2300 to 2550) during August 2004 with an average daily injection volume of 400 BWIPD. A coil tubing cleanout perfonned on 9/10/04 removed fill across the Sterling B-3 perforations from 5150' to the cement plug top at 5197' / MD. The wellhead injection pressure was not reduced appreciably, It was noted after the coil tubing cleanout that wellhead pressure dropped quickly to 800 psi when injection was stopped whereas it had previously only dropped to about 1600 psi. The wellbore is constructed with 3 Y2", 9.2 ppftubing in 9-5/8" casing, The tubing tail is at 4961' and minimum ill is 2.75". There is an Otis XL Ball Valve Nipple at 483' KB and an Otis XA Circ Sleeve at 4889'. The difference between GL and KB is 15', Objective: Acidize the Sterling B 1 through B3 perforations with mud acid to reduce wellhead injection pressure. - Procedure: 1. Spot liner on location as needed, Lay liner and benn under BJ Services acid transport and pump lines. Call out vac truck to supply filtered produced water to BJ Services pump to pressure test BJ Services pump lines and displace acid treatment down the production tubing, 2. MIRU BJ Services acid transport and enclosed fluid pump. NOTE: Tree flange connection is 4-1/16", 10K. Hold PJSM to discuss potential hazards and operational plan. Review MSDS sheets of all chemicals present and have appropriate PPE donned. Ensure pressurized eye wash container and Calcium Gluconate neutralizing kit for HF acid is on location. 3. MU pump lines ensuring that drip pans are placed under all connections. Record and report annulus pressure, injection rate, and injection pressure prior to beginning pumping operations, 4. Pressure test BJ Services pump lines to 4000 psi with produced water. Ma~um surface pressure not to exceed 2900 psi during acidizing operations, Page 2 of2 5, Commence pumping (bullhead) acid treatment as follows monitoring pressure and rates: a, 1000 gals, 7.5% HCL acid with additives @ 2 BPM b, 800 gals. 6% HCL and 1.5% HF acid with additives @ 2 BPM / c, 1200 gals, 6% HCL and 1,5% HF acid with additives @ 1 BPM d. 1000 gals. 7,5% HCL acid with additives @ 1 BPM e. 80 bbls, filtered produced water flush at 1 BPM. 6. RDMO BJ Services acid pumping equipment. Reinitiate produced water injection through BC facilities. Closely monitor rates, volumes, and surface injection pressures, 7. Please call Ken Walsh at 394-3060 or 283-1311 with questions and results. Beaver Creek #2 Sterling Acid Procedure KDW - 9/17/2004 11 :54:50 AM . . MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Camille O. Taylor (p'\ Chair DATE: July 12, 2002 ""'^ I SUBJECT: Mechanical Integrity Tests THRU: Tom Maunder ~q,'11V¡ Marathon Oil Co. P.I. Supervisor ttJh~,^O/ ~~~,~1;'3 FROM: Jeff Jones BCU Petroleum Inspector Beaver Creek Field NON- CONFIDENTIAL 4 P 4 P 1= Initial Test 4= Four Year Cycle V= Required by Variance W= Test during Workover D= Differential Temperature Test 0= Other (describe in notes) Test's Details Julv !b. ~ I traveled to Marathon Oil Coo's Beaver Creek Field water injection wells BC.,2 and BC-3 to witness 4 year MIT's. Pete Iverson was the Marathon representative in charge of testing today and he performed the task in a safe and proficient manner. The pre-test pressures were monitored for 15 min. and were found to be stable. The standard annulus pressure test was then performed on eath well, with both wells passing the MIT's. Summary: I witnessed successful MIT's on Marathon Oil Coo's w~ter injection wells BC-2 and BC-3 in the Beaver Creek Field, BCD. M.I.T.'s performed: ~ Attachments: Number of Failures: º Total Time during tests: ~ cc: ~'" blìo.u..r:T; IC.~ e\¡;lO'tBt:!:'tt;,.. ! 2 :I 2006 MIT report form 5/12/00 L.G. 020702-MIT BCU BC-2,BC-3 JJ.xls 7/2412002 Marathon Oil Company Alaska Region Domestic Production P.O. Box 196168 Anchorage, AK 99519-6168 Telephone 9071561-5311 Fax 9071564-6489 November 30, 2001 Mr. Tom Maunder~ Alaska Oil & Gas Conservation Commission 333 W 7th Ave Anchorage, Alaska 99501 Reference: BC 2 Dear Mr. Maunder: Enclosed is the REPORT OF SUNDRY WELL OPERATIONS form for Marathon well BC- 2 subsequent to acidizing. If you need any additional information, I can be reached at 907-564-6317 or by e-mail at dmtitus@marathonoil.com. Sincerely, Denise M. Titus ProdUction Engineer RECEIVED ORIGINAL g:~cmn\drlg\kgf~wells~ul 1-8sV~.OGCC02a..xls ,. STATE OF ALASKA ALASKA OIL AND GAs CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation Shutdown Stimulate __x Plugging Perforatem Pull Tubing Alter Casing m Repair Well Other~ 2. Name of Operator MARATHON OIL COMPANY 3. Address P. O. Box 196168, Anchorage, AK 99519-6168 4. Location of Well at Surface 590' FNL, 1979' FEL, Sec. 3, 6N-10W-SM At top of Productive Interval Straight Hole At Effective Depth Straight Hole At Total Depth Straight Hole 5. Type of Well: Development__ Exploratory__ Stratigraphic __ Service x 6. Datum Elevation (DF or KB) 15' KB above GL feet 7. Unit or Property Name Beaver Creek 8. Well Number BO -2 9. Permit Number 67-0026 10. APl Number 50--133-20021-00 11. Field/Pool Sterling 12. Present Well Condition Summary Total Depth: measured true vertical 15697' 15697' feet feet Plugs (measured) Effective Depth: measured true vertical 5221' feet 5221' feet Junk (measured) Casing Structural Conductor Surface Intermediate Production Liner Length 280' 2211' 8835' 10159' 282' Size 20" 13-3/8" 9-5/8" 7" 5" Cemented 525 SX 2000 SX 1370 SX 650 SX 41 SX Measured Depth 280' 2211' 8835' 15439' 15697' True Vertical Depth 280' 2211' 8835' 15439' 15697' Perforation Depth: B-1 B-1 b-2 B-3 B-3 5OO7'- 5O28' 5O32' -5O52' 5124'- 5140' 5155'- 5176' 5177'- 5197' MD MD MD MD MD 5007'-5028' TVD 5032'-5052' TVD 5124'-5140' TVD 5155'-5176' TVD 5177'-5197' TVD Tubing (size, grade, and measured depth) Packers and SSSV (type and measured depth) 3-1/2" N-80@4961' Baker FH Packer @ 4923' RECEIVED 13. Stimulation or Cement Squeeze Summary Intervals Treated (measured) B-l, B-2, and B-3 Treatment Description Including Volumes Used and Final pressure Refer to attached work history. DEC 0 1 2001 (31& Gas Cons. Commissi0~ 14. Representative Daily Average Production or Iniection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to Well Operation 0 0 15 0 1850 Subsequent to Operation 0 0 7O 0 1600 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of Well Classification as: Oil Gas Suspended Service x PL_ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~'" ~/~'~ D.M. Titus Title Production Engineer Date 11/28/01 Form 10-404 Rev. 06/15/88 ORiGiNAL Submit in Dupl~~ MARATHON OIL COMPANY~ DALLY WELL OPERATIONS RE PAGE 1 OF 1 DATE: 11/13/2001 FI ELD: Kenai Gas Field FILL DEPTH/DATE 5132' wlm 11/11/01 TUBING: 3 1/2" DATE LAST WL WORK: WORK DONE: Acidize Sterling Formation Disposal Interval OTHER: WELL #: BCU-2 CASING: TREE CONDITION: 4 1/2 EUE BENCHES OPEN: SUMMARY OF OPERATIONS NOTE: Tree connection is 4-1/2" EUE 8rd Felt and liner on location. MIRU BJ pump truck, load vac trucks w/filtered produced water (for flush). Place portable shower, eye wash station, etc. Held procedure and safety meeting. Discussed HC1, HC1-HF, and additive MSDS, emergency contingencies, and environmental awareness. Pressure test to 4000 psi. Looks good Pump produced water to establish injection rates/pressures as follows: 1 bpm-->2140psi; 2bpm-->2343 psi; 3 bpm-->2440 psi Beging pumping (bullhead) acid treatment as follows: Stage Pressure Rate (bpm) Note 1000 gal HC1 (7 1/2%) 2400 psig 3 2000 gal HC1-HF (7 1/2 -1 1/2%) 2500 psig 3 Max p=2500, dropped to 2324 when acid at perfs 1000 gal HC1 (7 1/2%) 2240 psig 3 Produced water 2500 psig 4 Displaced acid with produced water at max rate of 4 bpm at 2500 psi. BJ is analyzing fill sample to look at potential injection treatment. Annulus pressure did not change during job. No spills occured. SD acid operations. Clean up location and return well to injection. Leave liner for potential remediation 11/14/01 Injection rate: 15bph @ 1400psi (previously 10bph @ 1800psi) Vendor Equipment Daily Cost Cumulative Cost BJ Services Nitrogen & Pumping Service $32,250 $32,250 S&R Vac Truck $1,425 $33,675 APO Location Liner $2,500 $36,175 DALLY COST: $36,175 CUM: $36,175 REPORTED BY: Titus M, arathon O,ICompany A)ask~ Region DomesU~ Production P,O. Box 196168 Anchorage, AK 99519.6168 Telephone 907156t-53t 1 Fax 9071564-6489 November 7, 2001 Mr. Tom Maunder Alaska Oil & Gas Conservation Commission 333 W 7th Ave Anchorage, Alaska 99501 Reference: BC 2 Acidize Dear Mr. Maunder: Enclosed is the APPLICATION FOR SUNDRY APPROVALS form to pump an acid job on Marathon well BC 2. If you need any additional information, I can be reached at 907- 564-6317 or by e-mail at dmtitus(~marathonoil-com. Sincerely, · Denise M. Titus Operations Engineer RECEIVED NOV 0 Alaska 0il & Gas Cons. Commission Anchorage OEIGINAL 68kgk6~;G I6+ 110 HOHJ. V~tVW'm°J:I mdZ6:$0 STATE OF ALASKA ALASKA OiL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1, Type of Reque.~t: 'Datum"Eleva~lon (DF (~; KI~) t~' KB above GL Unit or PropeTty Name Beaver Creek Well Number BC-2 Permit Number 67-0026 APl Number nei~ooI ...... ~tedlng Abandon Suepend~ Operation Shutdown Re*enter Suspended Well.__. Ali[er Cae, ir',g -.-- Repair Well~ Plugg~g~ Time Extensior~ Stimulate.~x Changc Approved Program Pull Tubing Variance Perforate Other 2. Name of Operator MARATHON OIL COMPANY ] Development.__ fe ,e.,t___ 3. Address,, I Exploratory..._ ?. P. O. Box 196168, Anchorage, AK gg61g-6168 I Sttatigr~ph|c...__ 4. Location of Well at Surface Service_~.x 590' FNL. tgTg' FEL, See, 3. 6N-IoW-SM At top of Productive Interval St_./.ralght Hole At Etfectlve Depth Acidize Injection Welt to. ~Btraight Hole At Total Depth ~:1, Straight Hole tz. Present Well Condition Summon/ Total Depth' measured 15697' feet Plugs (me, outed) true vertical 15697' feet Effective Depth: measured 622~' {eet Junk (rnessured) true vertical 5~1' feet Casing Length Size Cernent~d Measured 0ep~h True Vertical Depth $fl'uctural Conductor 2BO' ~o" 525 SX 28o' 280' Surface 2211' 13-3/8" 2000 SX 221 t' 2211' Intermediate 88,36' g-5/8' 1370 SX 8~36' 8835' Pmdu ~tion 10159' 7" 650 SX 1543g' 15439' Liner 28~' ~" 41 S× 15697' 15697' Pelfor~tion Depth: measured B-1 5007' - S02.8' MD BOOT- 6028' TVD B-1 5032' . 506~.' MD 605Z - 5052' TVD B-2 5124' ~ 51,40' MD 5124'. 5140' TVD B.a 5155' - 5176' MD 5155'- 5176' TVD B-,3 5177' ~ S197' MD 5177'- 5197' TVD true vertical St. hole Tubing (size, grade, and measured depth) - Packers and $$$V (type and measured depth) 3-1/2' N-SO @4961' Baker FH Packer @ 4923' RECEIVED NOV 0 7 ,?,001 t4, Estimated Date for Comrnen~ing Operation t 1/12/2001 Proposal was Verbally Approved Prior t~ Modifications N~rne of Approve~ Date Approved t8. ~tatus of Well Classification as: IOil__ Gas.._,., Setvi~e Class II Disposal ~uspended~ 17. I hereb7 certify that the foregoing ia [rue and c~rreot to the best of my knowledge. . . 6ign?d .... ~ If~ Denise Titus Title Opera. tons Engineer FOR COMMISSION USE ONLY Conditions of Approval; Notify Commission so representative may witness Plug Integrity__ DOP Test__ Location Cleo range Mechanical Integrity Test__.. Subsequent Fo rrn Required lo-'-"L~ ~ Approved ,b.y, Ord. er .et the Commission [).S-:t Y0/~:0'd Original Signed By ~,,-,,.,,v n,~.h~li commissioner ~111111 ~' '~ ..... -,,,,,,,,, ORtGINAko,o, Date 11t7/~0ot ,, , ,%bn{It in 'r~nphcate mdZ~:~O [O-ZO-AO~ F rom-MARATHON O I L +9156646489 T-658 P.01/01 F-5TZ Marathon Oil Company Alaska Region BC 2 Beaver Creek, Pad 2 Acid Stimulate Procedure AFE # 0413801 History: Produced water from BC field is injected into Sterling benches in BC 2, Injection rate has dropped from 10 bbl/hr to less than lbbt/hr at 1740 psi, Objective: Pump acid to improve injection. Procedure: 1. RU BI pumping service. Spot liner under all lines and pumps, RU water source tank with 150 bbl filtered produced water, Gave vac truck on hand, 2. Hold safety and procedure meeting. Review MSDS for all chemicals, 3. Pressure test surface lines with fresh water to 3000psi. 4. Begin pumping acid per following schedule (be certain to observe pumping pressures): 1000 gal 7 V2 % HCI w/additives 2000 gal 6 1/2 % -1 1/2 % HCI-HF w/additives 1000 gal 7 Va % HC! w/additives 5. Displace acid with filtered produced water. Return well to injection as qtticldy as possible. 6. RDMO BJ pumping service and clean up location. RECEIVED NOV 0 7 2001 Alaska Oil & Gas Cor~s. Anchoraoe Perforations: Sterling B-1; 5007'~5028' 5o32'-5052' Sterling B-2: 5126'-5140' Sterling B-3: 51S$'-52Zo' 20' 94# · 12 3/8' 72e & SS# N-80 ~ 22t1' 4889' Otis XA circ sleeve 4923' Baker FH hyd pkr 4@61' Baker WL entry guide Cement Cap @5t97' Cement Retainer 7" liner stub 5268' g 5/8' 43.E~ N-a0 8rd @ 8836' 7" liner shoe @ 15,439' 5" liner shoe @ 15,697' Class II b~aposal Well B~ 0 B~: .... 0[ Oompletion Fluid: . _J ~w~: ..... .~..:" , I ~w.T,. .-'~,p,~.~: ....... ouT,,~', "~.. ' i ', Alask~ ~ion Domes.._ Production Marathon Oil Company P.O. Box 196168 Anchorage, AK 99519-6168 Telephone 907/561-5311 June 23, 2000 Mr. Blair Wondzell State of Alaska Alaska Oil and Gas Conservation Commisson 3001 Porcupine Drive Anchorage, Alaska 99501-3192 Reference: BC-2 Dear Mr. Wondzell: Enclosed is the completed REPORT OF SUNDRY WELL OPERATIONS form for well BC-2 and the schematic. Please advise if additional information is required. can be reached on 564-6303. Sincerely, Ralph J. Affinito Production Engineer Enclosure ,~:~., ~,~ 2 6 2000 Alaska 0if & Gas Cons, Commissio~ A~c~'i0r~9 A subsidiary of USX Corporation Environmentally aware for the long run. g:\cmn\drfCkgf~wells~ku 11-Ss'C. OGCC01a.xls STATE OF ALASKA " ALASKA OIL AND GAS CONSERVATION COI~MISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation Shutdown Stimulate ~ Plugging __ Perforate Pull Tubing Alter Casing __ Repair Well__ Other 2. Name of Operator MARATHON OIL COMPANY 3. Address P. O. Box 196168, Anchorage, AK 99519-6168 4. Location of Well at Surface 590' FNL, 1979' FEL, Sec. 3, 6N-10W-SM At top of Productive Interval Straight Hole At Effective Depth Straight Hole 5. Type of Well: Development Exploratory Stratigraphic Service x RECEIVED 2000 6. Datum Elevation (DF or KB) 15' KB above GL feet 7. Unit or Property Name Beaver Creek 8. Well Number BC-2 9. Permit Number 67-OO26 10. APl Number 50--133-20021-00 At Total Depth Straight Hole 12. Present Well Condition Summary Total Depth: measured true vertical 15697' 15697' Effective Depth: measured true vertical .Alaska 0ii & Gas Co~s. Commission feet Plugs (measured) feet 5221'feet 5221'feet Junk (measured) 11. Field/Pool Sterling ORIGINAL Casing Length Size Cemented Structural Conductor 280' 20" 525 SX Surface 2211' 13-3/8" 2000 SX Intermediate 8835' 9-5/8" 1370 SX Production 10159' 7" 650 SX Liner 282' 5" 41 SX Measured Depth 280' 2211' 8835' 15439' 15697' True Vertical Depth 280' 2211' 8835' 15439' 15697' Perforation Depth: B-1 5007'- 5028' MD B-1 5032' -5052' MD B-2 5124'- 5140' MD B-3 5155'- 5176' MD B-3 5177'- 5197' MD 5007'-5028' TVD 5032'-5052' TVD 5124'-5140' TVD 5155'-5176' TVD 5177'-5197' TVD Tubing (size, grade, and measured depth) 3-1/2" N-80@4961' Packers and SSSV (type and measured depth) Baker FH Packer @ 4923' 13. Stimulation or Cement Squeeze Summary Intervals Treated (measured) B-l, B-2, and B-3 Treatment Description Including Volumes Used and Final Pressure Refer to attached work history. 14. Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to Well Operation 0 0 36 BWPD 0 1850 Subsequent to Operation 0 0 15. Attachments 116. Status of Well Classification as: I Copies of Logs and Surveys run Daily Report of Well Operations X Oil__ Gas__ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~/ ~ Form 10-404 Rev. 06/15/88 75 BWPD 0 1650 Suspended__ R. Affinito Title Production Engineer Service Date 06/21/00 ~ Submit in Duplicate~[~ 02-08-2000 MARATHON OIL COMPANY ALASKA REGION Beaver Creek Field Well BC-2 Remedial Acid Stimulation Arrived in field, checked in w/BC personnel. Had spotted three Dowell Acid tanks the previous day. Acid was loaded into tanks previously. Pit liner was placed under all equipment and the tanks were lined and diked with pit liner. Held safety and environmental awareness meeting. Discussed acid safety and pressure safety. Mobilize fire extinguisher and pressurized eyes wash container to location. Have on location Calcium Gluconate nuetralizing kit for HF acid. Connected all lines placing drip pans under all connections and also pit liner below all surface lines to circumvent any spills. Annulus pressure before pumping job is 235 psig. Pressure test all surface lines to 3000 psig (both against Dowell valve and Swab valve) using produced water. Maximum surface pressure during job will be 2250 psig. Commence pumping (bullhead) acid treatment as follows: Product Pressure Rate Comment 320 gal xylene 2150 psig 1.00 BPM 970 gal 5% HC1 2115 psig 1.16 BPM 3045 gal HC1 ! HF Acid 2200 psig 1.26 BPM 794 gal 5% HC1 2200 psig 1.94 psig Gradual break when acid hit perfs. Max rate 1.75 BPM @ 2221 psig Displaced acid with 3738 bl~ (89 bbls) of produced water at max rate of 2.4 BPM at 2200 psig. Displacement volume to top perf is 56.6 bbls. Acid was thus overdisplaced by 32.4 bbls. Annulus pressure did not change during job. No spills occurred. SD acid operations. Clean up location and return well to injection. Pre-work Well Performance - Injecting 36 BWPD @ 1850 psig. '-' Subsequent Well Performance - Injecting 75 BWPD @ 1650 psig..- RECEIVED JUN 2 6 2000 Alaska Oil& Gas Cons. Commission Anchorage Attachment #3 ~ " 12-3/8", 72 & 8t! 80 L and J-55 to 2,211' 9-5/8", 43'.5# N-80 8rd csg Top of Cement @ 5,197' D~.L Bkr "K" rtnr 5,221' DIL (5,233' DPM) Bkr "K" rcnr ~,258' DIL (5,270' DPM) Beaver Creek #2 Wellbore Schematic Completed 10/14/82 20' CIW "DC-FBS" tbg hanger (3-1/2" EUE"Srd b x t) Ported for 1/4" control line 83'Otis "XL" Ball valve nipple ~' % (3-1/2". But~. p x b) 3-1/2" 9.2# Butt, N-80 tbg. 4,889 Otis XA circ sleeve (3-1/2" butt p. x b) 4,923' Bkr FH hyd pkr 3-1/2" butt p x b) ' ' 4,961' Bkr WL entry guide 5,125' - 5,140' B-2 (perfed 2/87) 5,.155' - 5,220' B-3 (squeezed 2/87) S/~, 5,155' - 5,175' B-3 (reperfed 6/87) .';,,,,.': 5,177' - 5,197' 5,230' - 5,244' B-3A al Top 7" Lnr stub 5,268' DIL (5,280' DPM) /_ 7" Lnr tie back slv 8,594' 9-5/8", 40, 43,5 & 47tt, N-80 & S-95 csg to 8,835' 5" Lnr top 15,415' 7", 29 and 32#, N-80 & P-Il0 to 15,439' 5", 18# FJ Hydrill to 15,.697' 5,263' - 5,265' 5,266' DiL 5,296' DPM 5,324' - 5,344' 5,600' 6,500' 8,400' - 8,715' 11,740' 11,950' 14,465' 14,680' 14,915' .. 15,407' 15,652' 15,697' Squeeze perfs Bkr "N" BP BOT hyd pkr B-4 2 HPF (perfed in error) Baker BP Ann cmt top Cmt in 7" Lnr Cmt top Baker BP Cmt top Bkr FB-I Perm pkr w/Q " FPEiVED Bkr "N" BP ; .IN 2 6 2000 · ~asr~a (~i & Gas Cons. Commission Anchorage Howco 7" Drillab'le C1BP PBTD TD NEF - 6/30/87 Alaska I-,,.gion Domestic Production Marathon Oil Company P.O. Box 196168 Anchorage, AK 99519-6168 Telephone 907/561-5311 May 15, 2000 Mr. Blair E. Wondzell State of Alaska Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Reference: Application for Sundry Approvals A~;cho~e Dear Mr. Wondzell: Please find the enclosed Application for Sundry Approvals for Well Number BC-2, procedure and schematic. If you have further questions or comments, please call me at 564-6303. Sincerely, Ralph J. Affinito Production Engineer Attachments A subsidiary of USX Corporation Environmentally aware for the long run. STATE OF ALASKA ~'~ ALASKA uIL AND GAS CONSERVATION COMMISSION APPLICATION FOR ,SUNDRY APPROVALS O:\EXCEL~ogcc.xls 1. Type of Request: Abandon Suspend Operation Shutdown Alter Casing Repair Well__ Plugging __ Change Approved Program __ Pull Tubing__ Variance Re-enter Suspended Well Time Extension Stimulate x Perforate Other 2. Name of Operator MARATHON OIL COMPANY 3. Address P. O. Box 196168, Anchorage, AK 99519-6168 4. Location of Well at Surface 590' FNL, 1979' FEL, Sec. 3, 6N-10W-SM At top of Productive Interval Straight Hole At Effective Depth Straight Hole At Total Depth Straight Hole 5. Type of Well: Development__ Exploratory __ Stratigraphic__ Service x 6. Datum Elevation (DF or KB) 15' KB above GL feet 7. Unit or Property Name Beaver Creek 8. Well Number BC-2 9. Permit Number 67-0026 10. APl Number 50--133-20021-00 11. Field/Pool Sterling 12. Present Well Condition Summary Total Depth: measured true vertical Effective Depth: measured true vedical Casing Structural Conductor Surface Intermediate Production Liner Perforation Depth: measured Length 280' 2211' 8835' 10159' 282' B-1 B-1 true vertical St. hole B-2 B-3 B-3 Tubing (size, grade, and measured depth) Packers and SSSV (type and measured depth) 15697' ~et 15697' ~et Plugs (measured) 5221' feet 5221' feet Junk(measured) Size Cemented 20" 13-3/8" 9-5/8" 7" 5" 525 SX 2000 SX 1370 SX 650 SX 41SX 5007'- 5028' MD 5032' -5052' MD 5124' ~ 5140' MD 5155'- 5176' MD 5177'- 5197' MD 3-1/2" N-80@4961' Baker FH Packer @ 4923' ORIGINAL Measured Depth 280' 2211' 8835' 15439' 15697' True Vertical Depth 280' 2211' 8835' 15439' 15697' 5007'-5028' TVD 5032'-5052' TVD 5124'-5140' TVD 5155'-5176' TVD 5177'-5197' TVD 13. Attachments Description Summary of Proposal .~X Detailed Operations Program__ BOP Sketch 14. Estimated Date for Commencing Operation May, 2000 16. If Proposal was Verbally Approved Prior to Modifications Name of Approver Date Approved 15. Status of Well Classification as: Oil __ Gas Service Class II Disposal Suspended__ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed R. Affinito ~-~/J2~ Title Production Engineer · ~' '~/W' 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- ~ C)~- ~RI(31NAL dl(,~r'~,,.: ....~.- - L~~'O~le~ O;V~ Approved by Order of the Commission D Taylor Seamoum .¢'9' ~et~-O-~r'~): ,~,-.~-~.-~"'~°mmissi°ner Form 10-403 Rev. 06/15/88 ~//~vl/ Date ] Appr°va~N~'a .., Date ~,~/~--' t~) ~ Submit in Triplicate BC-2 PRO-001 B. D. Millyard R. J. Affinito 05/15/00 Well: API Number: Legal Description: Elevations: Conductor Csg: Surface Csg: Intermediate Csg: Production Csg: Liner: TD/PBD: Beaver Creek Field - BCU g2 Acid Stimulation Procedure AFE # 0413600 BC-2 50-133-20021-00 590' FNL 1979' FEL, Sec 3, T6N R10W, SM 150' GL/155' KB 20" OD @ 280' cmt'd w/525 sks 13-3/8" OD @ 2211' cemented w/2000 sks 9-5/8" OD @ 8835' cemented w/1370 sacks 7" OD @ 5268'-15439' cemented w/650 sacks 5" OD @ 15415-15697' cemented w/41 sacks 15,697'/5188' KB 1 6 200 , Gas ~0~'~. ~;~rtm~si0n Anchorage Existing (Open) Perforations Formation I Interval I F~°ta'ge I Comments Sterling B-1 5007-5028 21' Open Sterling B-1 5032-5052 20' Open Sterling B-2 5125-5140 15' Open Sterling B-3 5155-5220 65' Tagged Fill @ 5188' in 09/92 Sterling B-3A 5230-5244 14' Below Fill Sterling B-3A 5263-5265 2' Below Fill & Squeezed Sterling B-4 5324-5344 20' Below Fill TOTAL 157' Current Status: Sterling Class II Disposal Well Last Representative Rate: 36 BWPD @ 1800 psig tbg pressure RECOMMENDATION Acids stimulate the BC-2 well using 4,000 gallons of Hydrochloric, Hydrofluoric, and Acetic acid. Return well to disposal. Wellhead injection pressure has gradually climbed to 1800 psig. Injection pumps are near exceeding their optimal operating range at this pressure. Acidizing the BC-2 generally occurs every 3 to 5 yrs and is a routine operation. PROCEDURE 1. OPTIONAL: RU Slickline unit. Hold safety and environmental awareness meeting. Install lubricator with BOP. Pressure test lubricator to 2,500 psig. RIH w/2.25" OD gauge ring tagging PBD. All equipment will have to pass through 2.75" tubulars. RD Slickline unit. Clean up location. RU Schlumberger pumping services. Call out vac truck with 90 bbls of filtered fresh water. Hold safety and environmental awareness meeting. Install drip pans under all trucks and absorbent pads under all connections. Pressure test surface lines to 3,000 psig using fresh water. Commence pumping acid stimulation at established rate less than 2,500 psig pump pressure while monitoring annular pressure. 500 gal 7-1/2% HCL w/additives 2500 gal 6-1/2% HCL + 1-1/2% HF w/additives 1000 gal 7-1/2% Acetic w/additives Displace acid w/50 bbls filtered fresh water. Observe shut-in wellhead pressures. RD pumping equipment and clean up location. Return well to disposal. Monitor injection rates and pressures following treatment. cc: D.R. Erwin "WRF" Page 1 WELL: ~CU-2 Soud Date, ?/13/67 0mgmal RKB, 155.1 KB TOD o~. Se?l~ng, 5.007' OIL Annulus Flulct, MARATHON OIL CDHFANY BEAVER CREEK UNIT API #, 1332002100 WeLL Co~tezlon O~e, 12/26/67 H~xlmu~ ~o[e An~le~ 0 degrees Ne~ Angle Through Sterling, 0 degrees Vorkover Reco~ote~on Reference Log, 0IL 8/6/67 ~EWELRY 20' 483' 4,889' 4,923' 4,961' CIV 'DC-IrBB Tbg Hanger (3-1/2'> SUE Brd b x t Par'tea For t/4' Control Line. 0tls 'XL' Ball Valve (3-t/~' ~utZ ~ x b> 0tls XA Cleo Sleeve ~ke~ FH Hy~' ~ker VL Entry G~de CASING & TUBING Size Veleht ~ 20' 94# H--40 13-3/8' 77..68~1 N--80.J--55 9--5/8' 40.4.~.5.47# N--80.S--gS 7' 29~ 7' 29.52~ N--80.P-110 5' 18~ FJ Hydrill ~--1/2' g.2# N--SO pI~RFI~RATIDN DATA lpterval Zone lr~T 5°007' - 5.0213' 13--I 21 5.032' - 5.052' 8-1 20 5,125' - 5,140' 8--2 15 5.155'- 5,220' 13--3 65 5,230' - 5.244' 13--.$A 14 5.263' - 5.265' 2 5.524' _ 5.54&' 13-4 20' F;H Tagged WLH 9/9~ ~197' Too of Cement ~2~1' Baker 'K' Re~mmer 5,266' Beke~'N° BP 5.296' 13OT HydP=¢k~ 5.600' Bok~ BP 8.400' - 8715' Cement in 7' Line~ IL740' Cee~t ToD IL950' Baker BP 0° 280' Coneuctor O' 2.211' Csg. 0' 8.835' CaD. 5.268' 8.594' Line~ Stub 8.594' 15.439' Linw 15.415' 15.697' Line~ 0' 4.961' 13uti Tbq. Squeezed (Perfed in error) RECEIVED ~ 0~! & ~3s C~s. Commission A~a~e 15,652' 15,697' 14,465' 14,680' 4,913' 15,407' PBTD TO Cement ToD Ba~er FB-I Per~ Packer w/ 0 NIOOle & Blanking Ptug Baker 'N' BP Howco 7' Dmttabte CIDP Revision Dote, 11/18/92 Revised By, TAM/eva Reason, Update Pervious RevlSlOn~ 2/89 TONY KNOWLE$. GOVEFINOFI ALASKA OIL AND GAS CONSERVATION COM~HSSION 3001 PORCUPINE DRIVE ANCHORAGE. ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 October 2v 1999 Lyndon Ibele Marathon Oil Company PO Box 196168 Anchorage, AK 99516-6168 Re' Authorization to Inject Produced Water from the Wolf Lake Development Area into Beaver Creek Unit Disposal Wells. Dear Mr. Ibele: By letter dated October 7, 1999 you have asked Commission for approval to inject produced water from future Wolf Lake area natural gas wells into two existing Beaver Creek Unit Class II disposal wells. Disposal Injection Order No. 4 limits injection in the Beaver Creek Unit//2 (BCU-2) well to nonhazardous oil field waste fluids. Disposal Injection Order No. 8 authorizes the injection of Class II oil field fluids into the Beaver Creek//3 (BCU-3) well. Other than the requirement that injected fluids be Class II in nature, the disposal injection orders place no limitations on the source of the injected fluid. Commission regulations. Alaska Administrative Code Title 20. Chapter 25 also do not limit the source of injected fluid. The Commission does not object to Marathon's request to transfer produced water from the Wolf Lake wells to the two permitted Class II disposal wells at Beaver Creek Unit. Marathon must maintain compliance with the conditions of the disposal injection orders and relevant Commission regulations at all times. Care must be taken to properly track and manifest waste material. Marathon should also ensure that adequate training is provided for any personnel handling waste prior to disposal. The Commission must be notified immediately if Marathon learns of any injection of waste that is not Class II into either the BCU-2 or BCU-3 wells. Sinc Robert N. Christenson. P.E. Chairman 1. Operafie. ns Performed: STATE OF ALASKA '""' ALASKA .. ,L AND GAS CONSERVATION CO~.,MISSION REPORT OF SUNDRY WELL OPERATIONS Operation Shutdown Stimulate X Plugging. Perforate Pull Tubing Alter Casing .... Repair Well Other 2. Name of Operat0¥ Marathon Oil Company 3. Address P.O. Box 196168, Anchorage, AK 99519-6168 4. Location of Well at Surface 590' FNL, 1979' FEL, Sec. 3, 6N-10W-SM At top of Productive Interval Straight Hole At Effective Depth Straight Hole At Total Depth Straight Hole 5. TyPe of Well: Development Exploratory Stratigraphic Service X 6. Datum Elevation (DF or KB) 15' KB above GL feet 7. Unit or Property Name Beaver Creek 8. 9, Well Number BC-2 ~ Permit Number/Approv_al Number APl Number 50-- 133-20021-00 11. Field/Pool Beaver Creek/Sterling 12. Present Well Condition Summary Total Depth: measured true vertical Effective Depth: measured true vertical Casing Length Structural Conductor 280' Surface 2211' Intermediate 8835' Production 10159' Liner 282' PerforatiOn Depth: measured true vertical Tubing (size, grade, and measured depth) Packers and SSSV (tyPe and measured depth) 15,697 feet Plugs (measured) 5221' - Retainer 15,697 feet 5,221 feet Junk(measured) 5188' - Fill 5,221 feet Size Cemented Measured Depth True Vertical Depth 20" 525 SX 280' 280' 13-3/8" 2000 SX 2211' 2211' 9-5/8" 1370 SX 8835' 8835' 7" 650 SX 15439' 15439' 5" 41 SX 15697' 15697' 5007-5028',5032-5052',5125-5140',5155-5220',5230-5244' 5007-5028', 5032-5052', 5125-5140', 5155-5220', 5230-5244' 3-1/Z', N-80,4961' md Baker FH Packer @ 4,923' FEB 28 1997 Alaska Oil & Gas Cons. Commissio~ Anchorage 13. Stimulation or Cement Squeeze Summary Acidized Sterling Perforations: See attached Operations Report Intervals Treated (measured) 5007-5028', 5032-5052', 5125-5140', 5155-5188' Treatment Description Including Volumes Used and Final Pressure 2000 gallons HCI, 2000 gallons HCI-HF, 1.07 bpm @ 1080 psig ORIGINAL 14. Prior to Well OPeration Subsequent to Operation 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations OiI-Bbl Representative Daily Average Production or Injection Data Gas-Mcf Water-Bbl Casing Pressure 140 150 - 782 16. Status of Well Classification as: Oil Gas m Suspended 150 Tubing Pressure 1650 1500 Service Class II Disposal Well 17. I hereby certify that the foregoing is true and corj~ct to the Signed _~J~~ Form 10-404 Rev. 06/15/88 best of my knowledge. Title Production Engineer Date 2/27197 Submit in Duplicate MARATHON OIL COMPANY DALLY WELL OPERATIONS REPORT PAGE 1 OF 1 DATE: 2/24/97 FIELD: FILL DEPTH/DATE: .518.8.' (9/,.9.2) TUBING: DATE LAST WL WORK: 12/25/'95 WORK DONE: Acidized well PRESENT OPERATION: Job complete PROBLEMS: problems starting charge pump, leaks Beaver Creek WELL #: BC-2 3.5" 9.2# N-80 CASING: 9-5/8" TREE CONDITION: Good BENCHES OPEN: B-l, 2, 3, 3A SUMMARY OF OPERATIONS Dowell on location. Spot and RU equipment. Vac truck loading 60 bbls produced water. Conduct safety, environmental, and operations meeting. Reviewed MSDS sheets. Problems starting charge pump. Charge pump running. PT to 2500 psig. OK. WHP = 0 psig, CP = 150 psig. Begin pumping 1000 gallons 7-1/2% HCl, followed by 2000 gallons of 6-1/2% HCl- 1-1/2% HF, 1000 gallons HC, I, and 56 bbls produced water. SI well. Well went on a vacuum after 2-1/2 minutes SI time. (See pump schedule below). WHP = 0 psig, CP = 150 psig. RD equipment. Cleanout acid tanks and haul 20 bbls fluid to Pad 41-18. Place well on injection. Pump summary: 0.65 bpm @ 1780 psig - Initial pump rate. 1.15 bpm @ 2020 psig - Increased rate. 0.98 bpm @ 2010 psig - slowed rate down as HCL hit perfs. Shutdown to fix leak. ISIP 1650 psig. Continue pumping. 0.93 bpm (~ 2010 psig - HF at perfs. 1.11 bpm @960 psig - HCI at perfs. 1.07 bpm @ 1080 psig - Final injection rate/pressure. SI well. Note: Stimulation of this well occurred when the mud acid hit the perfs. There was very little pressure change as the HCl (first stage) hit the perfs, and there was a pressure increase when the HCI (3rd stage) hit the perfs. For the next acid job, need to eliminate the HCl following the mud acid treatment, and consider eliminating the HCL in the first stage. Also need to switch to a liquid Iron Reducer since most of this solid product was still in the botttom of the tank at the end of the job - supposedly mixed at Great Western?!. Additives: 2 gal/1000 gal W54 (HC! & HCI-HF) 6 gal/1000 gal A261 Corrosion Inhibitor (HCI) 4 gal/1000 gal A261 Corrosion Inhibitor (HCI-HF) 150#/1000 gal L41 EDTA Iron Reducer (HCI & HCI-HF) WELL TESTS: BEFORE: AFTER: COMMENTS: MSCFPD BWPD TP CP DATE DAILY COST: $ 14,200 CUM: $ 14,200 REPORTED BY: Olson Soud Dote, 7/13/67 Orlglno{ RKB, 155.1 KB Too oF SerUng, 5.007' Annulus Fluid= Alt deD~hs ~e RKB ND top o~ HARATHON UIL CKIHFANY BEAVER CREEK UNIT API #, 1332002100 Como(etlon Date, 12/26/67 Hoxtmum Hole Angle, 0 degrees Angle Through Stet'ling, 0 degrees ReFerence Log= DIL 8/6/67 Nee Workover [] Re¢omotetlon ["1 OEW£LRY 20' 483' 4,889' 4,9~3' 4,961' CIW 'DC-FB8 Tbg Hanger 13-1/2') RUE 8rd b x t Ported For 1/4' Control Line. Otis 'XL' Boll Volve Nipple (~.75' I.D.) 13-1/~' Butt p x b) Otis XA Clrc Sleeve (~.75' I.]L) ]~aker FH Hyd Packer t~oker VL Entry Guide CASING & TUBING Size ~eloht 20' 94~ -- ' 4.0.4.3.5.,~7# 7' 29~ 7' 29.321 5' 181 3-1/z' Grade Too got:t:om Descrlot. N-40 O° 280' Cm~ductor N-80.J-55 O' 2.211' CaB. N-80.S-g5 O' 8.8,35' CaB. 5.268' 8.594' Liner Stub N-80.P-110 8.594' 15.4,39' Liner FJ Hydrill 15.415' 15.697' Liner N--80 0' 4.961' Butt Tbg, PERFI~RA TII~N DATA ZplFervol Zone Fl' 5,007' - 5,0~8' 8-1 21 5,03;~' - 5,0SP' B-I 20 5,1:~5' - 5,140' B--2 15 5,155' - 5,E~0' B-3 65 5?30' - 5.P44' B-3A 14 5.265'- 5.265' 2 5.324' _ 5.34~' B-4 20' F$tt Togged ~/LM 9/9E 5,197° Too oF Cement 5,~1' Baker 'K' Retainer 5,1~5B' I~oker 'K' Retam~ 5,266' Bak~ 'N' BP 5,296' BOT H~ Peck~ 5.600' Baker BP Squeezed (Perfed in error) 8,400' - 8715' Cement in 7' Liner 11,740' Cement Too IL950' BoWer BP 14,465' 14,680' 14,913' 15,407' Cement Too Baker FB-I Perm Packer w/ 0 NIOOte & Blanking PLug Baker 'N' BP Ho~co 7' Dmttobte CIBP FEB 28 1997 A~aska Oi~ & Gas Cons. Commission Anchorage 15,65~' 15,697' P~TD TD Revision Dote. 11/18/92 Revised By~ TAM/evo Re,scm Update Previous Revlslon~ 2/89 Alaska, Domestic Production Marathon Oil Company P.O. Box 196168 Anchorage, AK 99519-6168 Telephone 907/561-5311 January 28, 1997 Blair Wondzell Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501-3192 RECEIVED ,JAN 29 199'/' Alaska Oil & (~as Cons Anchorag'~ Commissio~ Dear Blair: Please find attached Sundry Form 10-403 requesting approval to stimulate Well BC-2 using a HCl/HF acid design treament. This well was last acidized December 1995. If you have any questions, please contact me at 564-6315. Sincerely, Michael R. Olson Production Engineer ORIGINAL Attachments cc: CEF A subsidiary of USX Corporation Environmentally aware for the long run. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon Suspend Operation Shutdown Alter Casing Repair Well, Plugging __ Change Approved Program Pull Tubing Variance Re-enter Suspended Well Time Extension Stimulate X ,, Perforate Other 2. Name of Operator MARATHON OIL COMPANY 3. Address P. O. Box 196168, Anchorage, AK 99519-6168 4. Location of Well at Surface 590' FNL, 1979' FEL, Sec. 3, 6N-1 OW-SM At top of Productive Interval Straight Hole At Effective Depth Straight Hole At Total Depth Straight Hole 5. Type of Well: Development ~ Exploratory __ Stratigraphic __ Service X 12. Present Well Condition Summary 6. Datum Elevation (DF or KB) 15' KB above GL feet 7. Unit or Property Name Beaver Creek 8. Well Number BC-2 9. Perrrtit Number 10. APl Number 50-- 133-20021-010 11. Field/Pool Steding RECEIVED Total Depth: measured 15,697. true vertical 15,697. Effective Depth: measured 5,221' true vertical 5,221' Casing Structural Conductor Surface Intermediate Production Liner Perforation Depth: measured feet Plugs (measured) feet true vertical Tubing (size, grade, and measured depth) 3-1/2" N-80 {~ 4,961' Packers and SSSV (type and measured depth) Baker FH Packer {~ 4,923' feet Junk (measured) feet Length Size Cemented Measured Depth 280' 20" 525 SX 280' 2,211' 13-3/8" 2,000 SX 2,211' 8,835' 9-5/8" 1,370 SX 8,835' 10,159' 7.' 650 SX 15,439' 282' 5" 41 SX 15,697' B-1 5,007' - 5,028' MD 5,007' B-1 5,032' - 5,052' MD 5,032' Straight ho B-2 5,124' - 5,140' MD 5,124' B-3 5,155' - 5,176' MD 5,155' B-3 5,177' - 5,197' MD 5,177' "rAN 29 1997 Alaska 0il & Gas Cons. Commission True ~e~l~CO~&th 280' 2,211' 8,835' 15,439' 15,697' - 5,028' TVD - 5,052' TVD - 5,140' TVD - 5,176' TVD 5,197' TVD ORIGINAL 13. Attachments Description Summary of Proposal X Detailed Operations Program__ BOP Sketch 14. Estimated Date for Commencing Operation February, 1997 16. If Proposal was Verbally Approved Name of Approver Date Approved 15. Status of Well Classification as: Oil Gas Service Class II Disposal Well Suspended. 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~~'~ Title Production Engineer FOR COMMISSION USE ONLY Date 1/28/97 Conditions of Approval: Notify Commission so representative may witness Plug Integrity BOP Test Location Clearance Mechanical Integrity Test 'Subsequent Form Required 10- Original Signed By David W. Johnston Approved bY Order of the Commission IApprova, No. ~q q- O t I~ Commissioner Date Form 10-403 Rev. 06/15188 Approved Copy c~/turr~ed S[{brr~/ in Triplicate Field/Platform: Beaver Creek Lease: A-028118 Site: Pad 2 Sand: B-l, 2, 3 (Sterling) KB: 15' Est Start Date: 2/18/97 Est Comp Date: 2/18/97 Marathon Oil Company Wireline Work Request Well BC-2 Packer: 4923' Tbg: 3-1/2" 9.2# N-80 EOT: 4961' Min ID: 2.75" (20°, 4889') Fill depth: 5188' Tree Connection 4-1/2" 8rd OBJECTIVE: 1/28/97 IPerform acid treatment to increase injection rate, and lower injection pressures. POTENTIAL PROBLEMS: Take precautions not to spill acid on personnel, or ground. Review MSDS sheets prior to job start and I wear proper protective gear. I LAST WELLWORK: 12/22/95 - Acidize well. PROCEDURE: 11. Have vac truck take on 70 bbls of filtered produced water at BC-la or BC 2 pad. 2. SI injection to well. 3. Conduct pre-job operational, safety and environmental meeting. Review MSDS sheets provided by Dowell and wear proper safety gear while handling acid. 4. RU pump and lines over lined area. Place absorbent pads around connections. 5. Install 2 pen recorder on wellhead. 6. PT surface lines to 2500 psi w/fresh water. (Haliburton pump truck will take on water at Pad la or 3). 7. Begin pumping acid per design. Acid can be displaced to top of perfs at 2 bpm (volume to top perf is 47 bbls), but rate should be slowed down to 1/2 bpm to 3/4 bpm as acid reaches perf (do not exceed an injection pressure of 2000 psig): 1000 gallons 7-1/2% HCI acid w/additives 2000 gallons 6-1/2% HCI - 1-1/2% HF acid w/additives 1000 gallons 7-1/2% HCI acid w/additives additives: 2 gallons/1000 gallons F75N Surfactant 2 gallons/1000 gallons A261 Corrosion Inhibitor 5 gallons/1000 gallons L41 EDTA Iron Reducer 8. Displace acid w/50 bbls produced water from vac truck. Water can be placed in acid tanks to flush out these tanks. 9. Put well on injection immediately after displacing acid. 10. RD pumping equipment using vac truck to vacuum lines dry. Empty vac truck at pad la ***Note tubing pressures at the beginning and end of each stage as the acid hits the perfs. QUESTIONS/CO M M ENTS? APPROVALS: Mike Olson, 564-6315 (Terry J. Kovacevich) E-mail to Don Erwin, BC Operators H:excel\wireline\bc\bc-2\003.xls WELL, ]]CU-2 Spud Dete, 7/13/67 OriglneI RKO: 155.1 KB Top o? Seriln9, 5,007' OIL Annulus FLuid, AIL depths ere RKB MD to top oF equipment, MARATHON OIL COMFANY BEAVER CREEK UNIT API #~ 1332002100 Completion ])ate, 12/26/67 HQxlmum Hole Angle, 0 degrees Angle Through Sterling, 0 degrees ReFerence Log, DIL 8/6/67 Well Type: CLass II DIspo~el New Workover [] Recompietlon [] JEWELRY 20' 483' 4,889' 4,923' 4,961' CIW 'DC-FB8 Tbg Henger (3-1/2') EUE 8rd b x t Ported For 1/4' Control Line. Otis 'XL' Bell Veive Nipple (P.75' I.D.) (3-1/2' Butt p x b) Otis XA Circ Sleeve (2.75' I.D.) Beker FH Hyd Pecker Beker WL Entry Guide ~ASING & TUBING Size Welaht 20' 94# 40,43.5.47# 7' 29# 7' 29.32# 5' 18# 3-1/2' 9.2# Grede To~ Bottom [lescmot. H-40 O' 280' Conductor N-80.J-55 O' 2.211' Cs§. N-80,S-95 O' 8,835' Csg. 5.268' 8.594' Liner Stub N-80.P-110 8.594' 15.439' Liner FJ Hydrill 15.415' 15.697' Liner N-80 O' 4,961' Butt Tbg. PERFF1RATIDN ~ATA ~nt~rvet Zone F_~.T 5,007' - 5,0P8' B-1 21 5,032' - 5,05P' 8-1 20 5,125' - 5,140' B-2 15 5,155' - 57;~0' B-3 65 5?30' - 5?44' B-,lA 14 5.263' - 5.265' 2 5.324' - 5,344' B-4 20' 5,188' Fill Tegged WLM 9/92 5,197' Top oF Cement 5,221' B(xker 'K' Reteiner 5,258' Beker- 'K' Retelnep 5,266' Beker 'N' BP 5.296' BOT Hyd P~icker 5.600' Baker BP Squeezed (Perfed in error) 8,400' - 8715' Cement in 7' Liner 11,740' Cement Top il950' Beker BP 14,465' 14,680' 14,913' 1~407' Cement Top Beker FB-I Perm Pecker w/ O Nipple & Btenklng PLug Beker 'N' BP Howco 7' Drlttebie CIBP 15,652' 15,697' PBTD TD Revision Dele, 11/18/92 Revised By: TAN/evo Re~som Update Previous Revtsiom 2/89 I=~ c-T~RXfi~e ~SP_.~T BY'MaraTllOll gl l Company ; 7-7.z-'oq~ ; z:u[l-'~ ; ~ B¥.*N~r,th,~ Oil CompinF' '8-t0-96 ; S:B~ ; FILE Pill, DEFqH/O~TE.;-'-~--~ ~_ TUBING:..... ! ~INQ: au,~T~ L.,~r Wi. WORK: .... -_ ....' ..... "" Wit='e OONOrnO~. .... ":: :- - = ~ ,,' ,,, ,-.mmmml~, , , Mn. Mn,w.,. '...Mm ,, , ,...--. , ,,. .......~ ~ ' "" '-" ..... ~ ,, ..... ~..q. ,,. ,. .... ~ '' ' .... '~'"' ' *' ~'h , t i ~, .. *~, ,, ,~o ,lei.lmm. WfL, I,, TE8?'t: MMSCFPO BV,/PO BEFOFIE; Alrr~R: '---'------- -------- · DAllY i~Oat: I ! CUM: lost-Il" brand fax tran~;mittal memo 7671 ~ ' " .... Perm ' ~.,. Ir-.~ # , " p.x # TP CP DATE RECEIVED JUL 2 2 199G Alaska 0il & Gas Cons. Commission Anchorage SENT B¥:~lara~hon Oil Company ; 7-22-~(:i ; 2'O§V~l ; Anchor age~ · .. '~", x'N,,x' P.~ RECEIVED dUi_ 2 2 1996 Alaska Oil & (]as Cons. Commission Anchorage STATE OF ALASKA ALASKA AND GAS CONSERVATION COi~, .... SSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation Shutdown__ Stimulate X Plugging__ Pull Tubing ~ Alter Casing Repair Well ~ Perforate Other 2. Name of Operator Marathon Oil Company 3. Address P. O. Box 196168, Anchorage, AK 99519-6168 4. Location of Well at Surface 590' FNL, 1979' FEL, Sec. 3 8N-10W-SM 5. Type of Well: Development ~ Exploratory __ Stratigraphic __ Service X 6. Datum Elevation (DF or KB) 15' KB above GL feet 7. Unit or Property Name Beaver Creek 8. Well Number BC-2 9. Permit Number/Approval Number 67-26 10. APl Number so-- 13320021-01 At top of Productive Interval Straight Hole At Effective Depth Straight Hole At Total Depth Straicjht Hole 12. Present Well Condition Summary Total Depth: measured true vertical ORIGINAL 1. Field/Pool Sterlin~l 15,697 feet 15,697 feet Plugs (measured) Effective Depth: measured true vertical 5,221 feet 5,221 feet Junk (measured) Casing Structural Conductor Surface Intermediate Production Liner Perforation Depth: measured true vertical Length 280' 2,211' 8,835' 10,159' 282' B-1 B-1 B-2 B-3 B-3 Size 20" 13-3/8" 9-5/8" 7" 5" 5,00 5,03 5,12 5,15 5,17 Cemented 525 SX 2,000 SX 1,370 SX 650 SX 41 SX - 5,028' MD - 5,052' MD - 5,140' MD - 5,176' MD - 5,197' MD Measured Depth True Vertical Depth 280' 2,211' 8,835' 15,439' 15,697' 5,00- 5,028' TVD 5,03- 5,052' TVD 5,12- 5,140'TVD 5,15 5,17 280' 2,211' 8,835' 15,439' 15,697' - 5,197' Tubing (size, grade, and measured depth) 3-1/2" N-80 @ 4,961' Packers and SSSV (type and measured depth) Baker FH Packer @ 4,923' JAN ] 0 T 96 Alaska Oi~ & Gas Cons, Commission Anchorage 13. StimUlation or Cement Squeeze Summary Intervals Treated (measured) B-1 (5007' - 5028', 5032' - 5052'), B-2 (5125'- 5140'), B-3 (5155' - 5220') Treatment Description Including Volumes Used and Final Pressure See attached Daily Well Operations Report 14. Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to. Well Operation 250 1740 Subsequent to Operation 380 1610 15. Attachments ~ 16. Status of Well Classification as: Copies of Logs and Surveys run ~ Daily Report of Well Operations ~ Oil Gas~ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Suspended Service Class II Disposal Well Title Drilling Superintendent Date Form 10-404 Rev. 06/15/88 Submit in Duplicate H:\EXCEL~,BC2RSWOI.XLS (nrs) MARATHON OIL COMPANY DAILY WELL OPERATIONS REPORT PAGE 1 OF 1 DATE: 12/22/1995 FILL DEPTH/DATE: DATE LAST WL WORK: WORK DONE: PRESENT OPERATION: PROBLEMS: FIELD: 5188' TUBING: 9/27/92 perf B-1 acid treatment Beaver Creek WELL #: BC-2 3-1/2" 9.3# L-80 CASING: 9-5/8" TREE CONDITION: BENCHES OPEN: B:1,2,3 (Sterling) SUM MARY OF OPERATIONS HWS arrived RU unit, checksan lines to Well Held safety meeting and discussed the procedure prior to PT after RU. Vac truck arrived loaded truck · with filtered produced water (approx. 90 bbls). WHP with injection pump S/I =600 psi on well, PT lines with fresh water to 2500 psi, tighten minor leaks PT good. S/I wing valve and start pumping KCL. Pump 1000 gals KCL at1.5 BPM, PIP= 2000 psi. 34 bbls away. Switch to HF acid. PI rate at .3/4 BPM pump, PIP=-1950 psi. 2000 gals, followed by the remaing KCL (1000) gals. All acid away, Pump 30 bbls to displace the tubing volume, PIP = 1500 psi. Used produced water in vac truck to clean out acid tanks and flush out the Haliburton lines. Pumped ·at total of 115 bbls of acid and liquid. Well went on vacuum. WHP-0 HWS rig off of well. Start injection pump. Pump rate at 620 BPD rate. With pressure increasing on the tubing. Acid consist of: 1000 gals 7.5% HCL acid w/additives 2000 gals 6.5% HCL 1.5% HF acid w/additives 1000 gals 7.5% HCL acid w/additives Additives: 2 gals/1000 gal pen-5 surfactant 2 gals/1000 gal HAL-85M corrosion inhibitors 25#/1000 gal. frechek A Iron Reducer ORIGINAL- WELL TESTS: BEFORE: AFTER: COMMENTS: MMSCFPD BWPD TP CP DATE DALLY COST: $ 8400 'CUM: $ REPORTED BY: Cissell &~rjp B¥:~aral:hon Oil ~, Tyi~ of R~: Company ;12-21-~D ;ll'D1u] ; Anchorage-, Al~r (=ming chmn~ N~m~m F'm0rmm STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS Rqzl~r Wail, t~ugolng__ 1lmm ~___ stlmulate~X l~l Tul~g V~rl~no~ ~ Other__ s. Type of W.,: Servl~ X ... ORIGINAL iii Plug, ='. Name of Openm~ I MARATHON OIL COMPANY ........ I ~ .......... ~u~, __ P.O. Bo~ 1~01.68, A ,,~,AK 9i~19.8t68 4. L°°ation of Well at 590' FNL, 1979' FEL, See. 3 6N-10W-SM At top o~ Produotlve Interval StraigM Hole At Elfeotl~ Depth StralgM Hole At Tdat Depth · St~ight Hole 12. pm~ent Wall Condi60n Summary Tot~; Dmh: memmur~ 15,697' tree vertioal 15,897' feet Junk Ef~c-th/e Der~: me~ 5,221' f.~ tm. vmtl~a~ $,221' feat mmaumd 280' 20" 2,211' t3.3/8" 8,835' 9-5/8" 10,159' 7" 282' ca~ng Stru~un~ Con~__~_r Intmmedlate Production Un.r Perforation Depth: B-1 B-1 B-3 B.3 Cemented 52S aX 2,000 SX 1,370 8X 5,007' - $,032' - 5,124' - 5,155' - 5,177' - 650 SX 41 SX 5,028' MD S,05Z MD 5.140. MD 5,176' MD 5,19T MD e. I:keum E'ki. atkm (DF ~r ~B) 15' KB above GL ' 7."b.# or pmpee/Nai~'~ ...... Beaver Creek 'a. W~ii Nul/tber ............... BC-2 .m O, Pem~lt N~m-bl' ........ lO, APl Number SO- 1~20021-01 t~. Rakl/Pool r~..q~[,~i ¥ i,..~,'" DEC 2 1 1995 Alaska 0ti a Gas Conm, Com~ ~ured Depth True VefllC,,) Depth 280' 2,211' 8,8:35' 15,439' 15,697' 5,00T - 5,032' - 5,124' - 5,155' - 5,17T - 280' 2,211' 8.835' 15,439' 15,697' 5,028' TVD 5.052' TVD 5,140. TVD $,176' TVD 5,191" TVD Tubing (else, grade, and meeeumd deplh) 3-1/2" N-80 (~ 4,061' Packers and SSSV (L~e and meam'ed doplh) Baker FH Peeker ~ 4,923' x ~1o ...... II ....... 1s. SMus of Wd Clmm#ke~n a~: ~:4, Ea..ted ~ f~ Comm,.~ag opam~m 12/22/95 Cla~s II Dmslx)sa! Well Suemnded_._ Name of Approver Dale 17. I'ha'eby certily Ihat tl~ _~._ng Is hue ~ cmtec~ to the beat o~"'~y knewledg.. Conditions of Approval: '"~otily C. emm~'ee ree~ may-~ Plug Integrity , BOP Teat '"' Original signeo uy 0avid W. Johnston ApprMd by Ord.r of U~.Comml.io. ....................... ~ENT BY:Marathon 011 Company ;12-22-~5 ; 7:5~A~1 ; Anc~o~ UU / Marathon O11 Company Wireltne Work Request Well BC-2 Field/Platform: Beaver Creek Packer: 4923' Lease: A-028118 Site; Pad 2 Tbg: 3-1/2" 9,2# N-80 Sand: B-l, 2, 3 (Sterling) EOT: 4961' (B', 1§' Min ID: 2,75" (20'. 4889') :.st Start Date', 12/22/95 Fill depth', 5188' Est Comp Date; 12/:22/95 Tree Connectior 4-1/2" 8rd OBJECTIVE: 12/20/95 tPefform acid treatment ~0 increase Injection rate, and lower Injection pressures." ... i POTENTIAL PROBLEMS: Take precautions not to spill acid on personnel, or ~round. Review MSDS sheets'Prior to Job start and wear proper protective .gear, LAST WIREUNE WORK: 9/27/92 Perf B-1 PROCEDURE: 1. Have voc truck take on 70 bbl~ of flffered produced water at BC-Io or BC 2 pod, 2. Si injection to well. 3. Conduct pre-Job operational, safety and environmental meeting, Review MSDS sheets ~rovtded by Haliburton and wear proper safety gear while handling acid, 4, RU pump and lines over lined area, Place absorbent pads around connections. 5, Install 2 pen recorder on wellhead. 6, PT surface lines to 2500 psi w/fresh water. (Haliburton pump truck will take on water at Pad 1oar 3), 7, Begin pumping acid per design. Acid con be displaced to top of parrs at 2 bpm (volume to . top peff is 47 bbis), but rate should be slowed down to 1/2 bprn to 3/4 bpm as acid reaches perf (do not exceed an Injection pressure of 2000 psig): 1000 gallons 7-1/2% HCI acid w/additives 2000 gallons 6-1/2% HCI- 1*1/2% HF acid w/additives 1000 gallons 7-1/2% HCI acid w/additives additives: 2 gallons/1000 gallons Pen-5 Surfactant 2 gallons/1000 gallons HAI-85M Corrosion Inhibitor 25#/1000 gallons Ferchek A Iron Reducer 7, Displace acid w/50 bbls produced water from voc truck, Water can be pJaced in acid tanks to flush out these tanks, 8, Put well on injection Immediately after displacing acta, 9, RD pumping equipment using vac truck to vacuum lines dry, Empty voc truck at pad la **'Note tubing pressures at the beginning and end of each stage os the add hits the perfs. QUESTIONS/COMMENTS? APPROVALS: .... ~ Fax to Don Erwin Mike Olson, ext. 315 (Mark F. Sinclair) (Terry J. Kovacevlch) RECEIVED DEC 22 1995 Alaska Oil & Gas Cons. Commission Anchorage H :excel\ wlrellne \ bc\ bc-2\ 001 .xls ~ENT BY:Marathon Oil Comp. any ;12-22-D5 ; 7:51~AM ; · '.'.,F:A i: '.',2;; '"'" '" ' · ,o._ , .,.,.'.~: 'i' , F;-,AVF;' F;.:i.~r.; [',fliT o., ,/~:LL, ~, '.-- '.-..: - '-' '::cud Da t.=: '.::.?./G7 P..r';q. lno. I ¢,7.".' 1&.:.5.! KR r,-,¢ of 3e-'tine), 5,Cg7' ..'3..~L Annt.l!,U$ :'-.,,O; -:F"I ~: i.':32.002100 .'; oraDte lion Dater :2/26/67 ;-.'.eference Lc,~: l.),_ 8/6/67 Anchorage~ Wor'kover' ~ Re¢or~ote'~ian [~ i [.5,658' t5.697' FwELR',' 4,889' 4,961' _::.W 'L1C-F.Aa Tb,:l H,mQer '..3-i/~':' CUE '.-':~*d b ~: .':. Pot'ted For ~./4' CoalPot BbS "XL' 3¢tlt V,'.~tve Nipple ¢a. 75' '..3-1f8' g,.~t;~ p :,. 2kis XA Circ Steeve (8,75' I,D.) Baker- Wi_ Entry Guide CAR1N0, '-:, TUBII}!!i ',,/.¢. iq'4i?_? ,: :"~r"acle I .;:O. '.) 4/! .,-I-,tO /2.671# .'!- 6(J,,J 55 :';' :,y~ 5,268' 29,5Ztt F..I- 80, P- 110 8,594' I~/} ¢',j avdrill 15.415' 9, 2,~ ;.i - 80 O' 280' 2.211' .P,,,835' .~,594' 15,439' ',5,697' 4,961' PERFf'JR .~T)UN DATA .f n i: ~,r.v_~ .70 DP,, FT 5,007' - 5,028' B-; 21 5,038' "b.052' W .'.I 20 5, t25' '- "L140' B-2 ~5 5, t55' - 5,220' B-,..5 65 ..-t5,~.30' - '-.'1, ~44' El -- 5A 1 g, 5.263' - :'.,265' 2 '~;queeze¢ 5,52,;' - ..,.344' 8-4 20' (Perfed in error) Csq. Liner Liner 5,188' ,--ill Tag.~ed WLM 9/92 5, t97' fop OF L'er~ent 5.266' ~oker 'H' BP b,298' SOT IIvr: P,:,'.'k~r 5,600' ~q,.lk er uP :i,400' .- 3715' ,:.,,f~en~ :n ?" liner 11,740' Cement 11,950' Baker" BP 14.,465' 14,&gO' t .'!.,':~ t 3' !5.401' H.o~co 7' 2,-,do. hie RECEIVED DEC 2 2 1995 Alaska Oil & Gas Cons. Commission PBTD TD Revision Dote: It,liS.~92 Revised By: TAM/evo Re~¢on: Ljpc~ate Previ~ I~evl$1on, 2/89 Alaska, .~n Domestic ,~roduction Marathon Oil Company P.O. Box 196168 Anchorage, AK 99519-6168 Telephone 907/561-5311 July 12, 1995 Joan Miller Alaska Oil & Gas Conservation Commission 3001 Porcupine Dr. Anchorage, AK 99501 Dear Joan- Per your request, please Sundry notices' BC-2 Form 10-404 BC-3 Form 10-407 BC-7 Form 10-404 find attached the following Subsequent Acidize Sterling B-I, 2, 3 injection zones Recomplete as a Sterling B-lB injector WSO and Reperf Sterling B-3 Should you have any questions regarding this report, please contact Mike Olson at (907) 564-6315. RECEIVED JUL 1 7 1995 Oil & Gas Cons. CommissiOn Anchor:,,,° Sincerely, Mark F. Sinclair Drilling Superintendent Encl. A subsidiary of USX Corporation Environmentally aware for the long run. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations pedormed: Operation shutdown __ StimulateX-- Plugging __ Pull tubing __ Alter casing __ Repair well __ Perforate m Other 2. Name of Operator Marathon Oil Company 3. Address P.O. Box 196168, Anchorage AK 99519-6168 4. Location of well at surface 590' FNL, 1979' At top of productive interval .~ Straight Hole At effective depth Straight Hole At total depth Strai.ght Hole FEL, Sec. 3 6N-lOW-SM 5. Type of Well: Development __ Exploratory __ Stratigraphic __ Service -X- 6. Datum elevation (DF or KB) 15' KB above GL 7. Unit or Property name Beaver Creek 8. Well number BC-2 9. Permit number/approval number feet 10. APl number 5o- 13320021-01 11. Field/Pool Sterl i ng 12. Present well condition summary Total depth: measured true vertical Effective depth' measured true vertical Casing Length Structural Conductor 280' Surface 2,211 ' Intermediate 8,835 ' Production 10,159 ' Liner 282 ' Perforation depth: measured true vertical Tubing (size. grade, and measured depth) 3-1/2" N-80 @ 4,961' Packers and SSSV (type and measured depth) Baker FH Packer @ 4,923' 15,697' feet 15,697' feet 5,221' feet 5,221' feet Plugs (measured) Junk (measured) Size Cemented 20" 525 sx 13-3/8" 2,000 sx 9-5/8" 1,370 sx 7" 650 sx 5" 41 sx B-1 5,007' - B-1 5,032' - B-2 5,124' - B-3 5,155' - B-3 5,177-' - Measured depth 280' 2,211' 8',835' 15,439' 15,697' 5,028' MD 5,052' MD ' 5,140' MD 5,176' MD 5,197' MD 5,007' 5,032' 5,124' 5,155' 5,177' True vertical depth 280' 2,211' 8,835' 15,439' 15,697' 5,028' TVD 5,052' TVD. 5,140' TVD 5,176' TVD 5,197' TVD 13. Stimulation or cement squeeze summary Intervals treated (measured) .See Attachment #1 "BC-2 Acid Treatment" Treatment description including volumes used and final pressure 14. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Md Water-Bbl Casing Pressure Tubing Pressure Prior to well operation Subsequent to operation 15. Attachments Copies of Logs and Surveys run __ Daily Report of Well Operations ~ Attmt I 16. Status of well classification as: Oil __ Gas __ Suspended __ Service C 1 ~a s s II Disp~)sal 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~¢.~~. ~"' Form 10-404 Rev 06/15/88 Title Date 7--t/ ~ -~' ~ SUBMIT IN DUPLICATE Jell BC-2 ACID TREATMENT 2/22/94 Conduct safety meeting. R/U injection pump. PT equipment to 2000 psi. O.K. Pump 250 gallons 15% HCl w/inhibitors into open Sterling B-l, 2, 3 perfs. R/D equipment. Return well to injection. ~ & 6~s ~0~s' C,o~tss'~o~ L.-~""3artez Pr~_~tion Manager Alaska Region Domestic Production Marathon Oil Company November 15, 1994 P.O. Box 196168 , · ,' Anchorage, AK 99519-6168 Telephone 907/561-5311 Mr. Blair Wondzell A.O.G.C.C. 3301 Porcupine Dr AnchOrage, Ak. 99508. Dear Mr. Wondzell, This letter is intended to correct reporting discrepancies, for the gas production and gas injection wells, in the Beaver Creek Field. The confusion centers around BC-1A. From 1974 to 1982 BC-1A was both an gas injection well and a gas producing well. To eliminate flaring Beaver Creek oil well formation gas, the gas was injected into BC- lA. Gas was also taken from BC-1A to supply lift gas and fuel gas to the Beaver Creek oil wells. State reports reflect the gas was injected into the Beluga formation (reservoir # 500). State reports should reflect gas injection into the Sterling formation (reservoir # 525). Below is a table summarizing gas production and gas injection thru 7/94 as you requested. Production Cumulative Well Formation Phase Start Last Water(BBL) Gas(MCF) BC-1A Beluga Production 1/89 Active 63,707 3,025,587 BC-1A Sterling Production 1/73 12/89 86,523 11,453,266 , BC-2 Sterling Production 5/74 1/87 308 4,718 , · BC-3 Sterling. Production 9/82 ..10/88 199,351 1.9,108,167 , BC-7 Sterling Production 11/82 7/93 162,950 41,647,224 BC-6 Sterling Production 9/82 - 3/94 57,493 51,564,301 , BC-1A Sterling Injection 1/74 9/82 0 507,592 , BC-6 Beluga Injection 9/82 10/83 0 43,464 If you need ad..ditionai information please give me a call at 564-6410. G~~ cc'Marcus Allen Engineering Manager Mark Sinclair Operations Manager Roger Good Accounting Supervisor RECEIVED NOV I 6 1994 Environmentally aware for the long run. Alaska ;ion 'Domestic Pi'oduction Marathon Oil Company P.O. Box 196168 Anchorage, AK 99519-6168 Telephone 907/561-5311 February 18, 1994 Mr. Blair Wondzell Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 RE: Beaver Creek Well 'BC-1A Dear Mr. Wondzell: Attached for your approval is the AOGCC "Application for Sundry Approvals" to perform an acid stimulation on disposal Well BC-2. Should you have any questions regarding this application, Please contact me or Mr. Ed Oberts at (907) 564-6436. Sincerely, Operations Engineering Supervisor LCI/EVO/cah Enclosures RECEIVED FEB 2 8 1994 Alaska 0il & Gas Cons. Commission Anchorage A subsidiary of USX Corporation Environmentally aware for the long run. STATE OF ALASKA ALASr~A OIL AND GAS CONSERVATION COMrvmsSION · APPLICsATION oFO SUNDRY APPROVALS 4:,. Type Requ : Abandon Su pend perat* n shutdown Re-enter suspended well I~'~ Alter casin'~-~ Repair w~...._ Plugging ~ -- Time extension__ Stimula"~' X._~. j Change approved program__ Pull Tubing__ Variance__ Perforate__ Other m 2. Name of Operator I 5. Type of Well: 6. Datum elevation (DF or KB) Marathon Oil Company . . ' I D;v;~?oPra~:nr~-- _ 15' KB above G_~L fe~t 3. Address I Stratigraphic ~ 7. Unit or Property name P. O. Box 196168 Anchorage, AK 99519 I Service'X- Beaver Creek 4. Location of well at surface 8. Well number 590' FNL, 1979' FEL, Sec. 3 6N-10W-SM BC-2 At top of productive interval Straight Hole At effective depth Straight Hole At total depth Straight Hole 12. Present well condition summary Total Depth: measured true vertical RECEIVED 15,697' 15,697' FEB 2_ 8 1994 Naska 0il & Gas Cons. Commission feet Plugs (measured) feet 9. Permit number/approval number 67-26 O. APl number 50- 13320021-0.~ 1. Field/Pool Sterling Effective depth: measured true vertical Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: measured 5,221' 5,221' Length 280' 2,211' 8,835' 10,159' 282' true vertical Tubing (size, grade, and measured depth) 3-1/2" N-80 @ 4,961' Packers and SSSV (type and measured depth) Baker FH Packer @ 4,923' feet Junk (measured) feet Size Cemented 20" 525 sx 13-3/8" 2,000 sx 9-5/8" 1,370 sx 7" 650 sx 5" 41 sx B-1 5,007'- 5,028' MD B-1 5,032'- 5,052' MD B-2 5,124'- 5,140' MD B-3 5,155'- 5,176' MD B-3 5,177'- 5,197' MD Measured depth True vertical depth 280' 280' 2,211' 2,211' 8,835' 8,835' 15,439' 15,439' 15,697' 15,697' 5,007' - 5,028' TVD 5,032'- 5,052' TVD 5,124' - 5,140' TVD 5,155'- 5,176' TVD 5,177'- 5,197' TVD 13. Attachments Description summary of proposal X Detailed operations program__ BOP sketch Estimated date of commencing operation 15. Statis of well classification as: February 22, 1994 If proposal was verbally approved Oil m Gas __ Name of approver Date approved Service Class II Disposal Well 17. I hereby certify thatJhe foregoi~.ng is,~e,a/~ correct to the best of my knowledge. Signed ~/'~ ~/,,~//~ Title Operations Engineering Supervis°r . .~. / ~. { ~/'~i. FOR COMMISSION USE ONLY Conditions ~f,~PlugPiPnrtOeV;rli:ty Notify-Co~ipSs~eOsnt so represeLnotcat~ieonmc~eY~r iatnn(~eSS Suspended Date ~,,/Oc~.///~ ~ I Approval No. Mechanical Integrity Test__ Subsequent form required lO- ~Pp~oved Copy Returned Original SJgne( By Approved by order of the Commision David W. Johnston Commissioner~ ' Date ~/.c//2 cr Form 10-403 Rev 06/15/88 SUBMIT IN TRIPLICATE BEAVER CREEK WATER DISPOSAL WELL #2 PROPOSED ACID TREATMENT PROPOSED START DATE: 2/22/94 1. Conduct safety meeting. 2. R/U Halliburton. Lay Visqueen under all equipment to contain any drips. 3. Pressure test lines to 3,000 psi. 4. Pump 250 gal 15% HC1 with inhibitors into tubing. Maintain injection pressure less than 2,000 psi. 5. Displace the acid with 100 BBLS water using injection pumps. monitor injection pressure peroidically. h:\wp\bc2acid RECEIVED FEB 2 8 1994 Alaska Oil & Gas Cons. Commission Anchorage ~/ELL~ ]~CU-2 Spud Date; 7/13/67 Original RKB, 155.1 KB Top oF SerUn9, 5,007' ])IL Annulus Fluid; All depths are RKB MI) to top oF equipment, MARATHON OIL COMPANY BEAVER CREEK UNIT API #-' 1332002100 Completion Date, 12/26/67 Haxlmum Hole Angle, 0 degrees Angle Through Sterling, 0 degrees ReFerence Log, OIL 8/6/67 Well TypeJ Class II ])lsposa[ New [] ~orkover [] Re¢ompletlon [] JEWELRY 20' 483' 4,889' 4,923' 4,961' CI~/ '9C-FB8 Tbg Hanger (3-1/2') CUE 8rd b x t Ported For 1/4' Control Line. Dtis 'XL' Ball Valve Nipple (2,75' I.D.) (3-1/2' Butt p x b) Otis XA Clrc Sleeve (2.75' I.:D.) Baker' FH Hyd Packer' Baker ~/L Entry Guide CASING & TUBING Size Weight Grode 20" 94// H-40 40,43.5,47# N-80,S-95 7" 29// 7" 29,32// N-80,P-110 5" 18~ FJ Hydrill 5-1/2" 9.2// N-80 PERFDRATIDN ])ATA Interval Zone F_iT 5,007' - 5,028' B-1 21 5,032' - 5,052' B-1 20 5,125' - 5,140' B-2 15 5,155' - 5,220' B-3 65 5,230' - 5,244' B-SA 14 5,263' - 5,265' 2 5,324' - 5,344' B-4 20' 5,188' Fill Tagged WLM 9/92 5,197' Top oF Cement 5,221' Baker' 'K' Retainer 5,258' Baker 'K' Retainer 5,266' Baker 'N' BP 5,296' BOT Hyd Packer 5,600' Baker BP T_.9.D_ Bottom ])esCrlDt. O' 280' Conductor O' 2,211' Csg. O' 8,855' Csg. 5,268' 8,594' Liner Stub 8,594' 15,459' Liner 15,415' 15,697' Liner O' 4,961' Butt Tbg. Squeezed (Perfed in error:) 8,400' - 8715' Cement in 7" Liner 11,740' Cement Top 11,950' Baker BP 14,465' 14,680' 14,913' 15,407' Cement Top Baker FB-I Perm Packer w/ D Nipple & Blanking Plug Baker 'N' BP Howco 7' Drlilable CIBP RECEIVED FEI3 2 8 1994 Alaska Oil & Gas Cons. Commission Anchorage 15,652' 15697' PBT9 TD Revision Date, 11/18/92 Revised By: TAM/eva Reason, Update Pr'evious Revision= 2/89 I I I GI;~F:IN [ T E KING .~t_MON RRCO UNOCPI- ~R~THON vRRI~N HFERTHON BRY c DILLON ' LINCXSRL FRCILITY GRRNITE POINT M~RRTHO~ I'RFIDING BRY-I-[1 C~IST¥ KENRI FIELD ~':'-')' f tl_l- t5]t<f:t \ VICINII¥ grip / / / / / mLUC~ ~ r I[LII I 4 \ \ I I ~I~R r_)qS FIELD NIJ~ltl COO~ IN.E1 BIRCH HILL FI[LO [ c.i~ol~ RIvLR OIL/C~I~ FI£LD LEGEND E NSTIqR PIPELINES NftTIJRftL C~S PIPELINE (fiLl. OillERSI Ala~ LIQUID PETROLEUM PIPELINES OIL & GRS PLRI'FORM 01L ,'C;:IS FIELDS l_~Sr RE'VISION: JRNURRY 19g~ ,t PRLn£R RECEIVED ~66t~t NLE T FiRE R ka 0il & Gas Cons. Commission ~!~h~aIllEL I NE MRP ENBTAR -" I:.N..~I'ItI~ hl,~L(fr ,.ti (;,-~; f:l I]IV[%L()N ()1:- '.,t I/(,lll I f~. 0 1~):< 1(' t'tnchr)r(~cj~.~, Ftl,~:-:k,~ 't!J'.)l!i .................................... Unocal North American Oil & Gas Division Unocal Corporation P.O. Box 190247 Anchorage, Alaska 99519-0247 Telephone (907) 276-7600 UNOCAL Alaska Region DOCUMENT TRANSMITTAL December 1, 1992 TO: Larry Grant LOCATION: 3001 PORCUPINE DRIVE ANCHORAGE, AK 99501 ALASKA OIL & GAS CONSERVATION COMM. FROM: Eric Graven LOCATION: P.O.BOX 196247 ANCHORAGE AK 99519 UNOCAL TRANSMITTING AS FOLLOWS BEAVER CREEK//2 1 blueline and 1 sepia Completion Record ¢/'/ BEAVER CREEK//4 1 blueline and 1 sepia Peroration Depth Record PLEASE ACKNOWLEDGE RECEIPt BY SIGNING AND RETURNING ONE COPY OF THIS DOCUMENT TRANSMITTAL. THANK YOU RECEIVED BY: /~~'~ .~-----, DATED: REC VED Anchorage Alaska ion Domestic Production Marathon OilCompany RO. Box 190168 Anchorage, AK 99519-0168 Telephone 907/561-5311 November 11, 1992 Mr. D. W. Johnston Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Johnston: Enclosed is the AOGCC "Report of Sundry Well Operations" with the appropriate attachment for Beaver Creek Well #2. Should you have any questions regarding any application or report, please contact E. V. Oberts at 907/564-6436. Si. n~. ~ Ibele Operations Engineering Supervisor LCI/EVO/crc Attachment cc E. V. Oberts H: \wp\Sundry. [ tr RECEIVED NOV 1 1992 Alaska Oil & Gas Cons. Commission Anchorage A subsidiary of USX Corporation STATE OF ALASKA ~ f~ -' ALA~'KA OIL AND GAS CONSERVATION COMMIbo~ON REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown __ Stimulate __ Plugging ~ perforate X Pull tubing ~ Alter casing __ Repair well __ Other IGINAL 2. Name of Operator ! 5. Type of Well: Marathon Oi l Company I Development Exploratory 3. Address Stratigraphic P.O. Box 190168 Anchorage, AK 99519 Service-~- 4. Location of well at surface 590' FNL, 1,979' At top of productive interval Straight Hole At effective depth Straight Hole At total depth Straight Hole FEL, Sec. 3 6N-lOW-SM 12. Present well cOndition summary Total depth: measured true vertical 15,697' feet 15,697' feet Plugs (measured) Effective depth: measured 5,221 ' true vertical 5,221 ' Casing Length Structural Conductor 280' Sudace 2,211 ' Intermediate Production 8,835 I Liner 10,159' 282' Perforation depth: measured 13 true vertical Tubing (size, grade, and measured depth) 3 1/2" N-80 e 4,961' Packers and SSSV (type and measured depth) Baker FH Packer ~ 4,923' feet feet Junk (measured) Size Cemented 6. Datum elevation (DF or KB) 15' KB above GL 7. Unit or Property name R~vPr ~,r~k Ilnlf 8. Well number BO-2 9. Permit number/approval number 67-26/92-242 feet t0. APl number 50- 13320021-0~ 11. Field/Pool Sterling REEEIVED N OV 1 ;~ 1992 Alaska 0/I & Gas Cons. 6ommiss Anch0r~e Measured depth True vemcaroepth 20" 525 sx 280' 3/8" 2,000 sx 2,211' 5/8" 1,370 sx 8,835' 7" 650 sx 15,439' 5" 41 sx 15,697' B-1 5,007' - 5,028' MD 5,007' - B-1 5,032' - 5,052' MD 5,032' - B-2 5,124' - 5,I40' MD 5,124' - B-3 5,155' - 5,176' MD 5,155' - B-3 5,177' - 5,197' MD 5,177' - 280' 2,211' 5,028' TVD 5,052' TVD 5,140' TVD 5,176' TVD 5,197' TVD 8,835' 15,439' 15,697' 13. Stimulation or cement squeeze summary Perforate B-1 (new interval) from 5007'-5028' and 5032'-5052' DIL, Intervalstreated (measured) Sterl i ng B- 1,2,3 2000 gal Xylene .1/4 BPM ~ 2180 psi. Treatment description including volumes used and final pressure 2000 gal 10% HC1 3BPM ¢. 2000 psi, 14. Prior to well operation Subsequent to operation RepresentativeDailyAverageProducbonorlnjectionData OiI-Bbl Gas-Md WatePBbl Casing Pressure 146 ~'~ 220 816~ 190 Tubing Pressure 1670 1800 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: Oil __ Gas __ Suspended __ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~~,~. ~(~/~ Title Operati ons Form 10-404 I~v 06/15/88 - ' - Service C 1 a s s I I Dis PoS a 1 Enaineerina SUBMIT IN DUPLICATE DALLY NELL OPERATIONS BC-2 9/26-27/92 $W5. Held safety mtg. PT lub to 2500 psig. OK. Est comm blackout above/below 500'. RIH w/ 2-1/8" strip guns, DP13 gr CG$. 0 degree phased, 0 degrees offset. 4$PF and perforated the following intervals: Run //1 5032 - 5052 KB Misfired Run //2 5032 - 5052 KB Fired Run //3 5007 - 5028 KB Fired Test, 100 BWIPD at 1500 PSIG. RD and evaluate stimulation. 9/30/92 Halliburton on location. Environmental and safety meeting. Xylene on location. Pressure test lines to 2000 psi. Good test. Start pumping xylene down tubing TP = O, CP = 180. Psi up 1500, < 1/2 BPM, CP = 180. 48 bbls xylene pumped. RD Halliburton. Displace xylene to perfs with 45 bbls filtered produced water. 10/1/92 Displacing xylene into formation using WI pump. 48 bbls filtered prod. water pumped. SD pump. Prior to shut down, 2180 psi indicated rate was 360 BWIPD. Halliburton on location. Hold safety, environmental meeting. RU on well. Pressure test lines to 3000 psi. Good test. RU suction line to acid tanks. Start pumping 2000 gal 104 HC1 w/ 0.24 HAI-85M, 0.24 Lo surf 300 and 20 lb/lO00 gal iron sequestering agent. 3BPM, 2000 psi. All acid pumped. Displaced w/ 50 bbls prod. water. RD and return well to injection. H: \wp\WE L LOPS\BC2 R ¢EIVED NOV 1 ) 1992 Alaska Oil & Gas Cons. Commissior, Anchorage Alaska t on Domestic Production Marathon Oil Company RO. Box 190168 Anchorage, AK 99519-0168 Telephone 907/561-5311 September 29, 1992 Mr. D. W. Johnston Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Johnston.' Enclosed is the AOGCC "Application for Sundry Approval" with appropriate attachments for Beaver Creek Well #2. Should you have any questions regarding any application or report, please contact E. V. Oberts at 907/564-6436. Sincerely, Operations £n§ineering Supervisor LCI/EVO/crc Attachment cc E. V. Oberts ;~*~Orag~ C°/~i~$ion H: \wp\Sundry. [ tr A subsidiary of USX Corporation STATE OFALASKA 0 RIG IN A £ ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon __ Suspend __ Alter casing __ Repair well Change approved program __ Operation shutdown ~ Re-enter suspended well __ Plugging ~ Time ex'tens,on __ Stimulate ~ Pull tubing ~ Variance __ PedorateXX Other __ / 2. Name of Ope.rator | NarathOn 0il Company 3'Addre~.s0. BOX 190168 Anchorage,'AK 995 9 FEL, Sec. 3 6N-IOW-SM 4. Location of well at surface 590' FNL, 1,979' At top of productive interval Straight Hole At effective depth Straight Hole At t°t~ ~"[:)att h] g h t Hole 5. Type of Well: Development Exploratory Stratigraphic Service 6. Datum elevation (DF or KB) 15' KB above GL 7. Unit or Property name Beaver Creek Unit 8. Well number BC-2 9. Permit number 67-26 10. APl nUmber 5o-13320021-00~4 11,,. I~ield/,P.ool bier/I ng feet 12. Present well condition summary Total depth: measured true vertical 15,697' feet 15,697' feet Plugs (measured) Effective depth: measured true vertical 5,221 ' feet 5,221' feet Junk (measured) Casing Length Structural Conductor 280' 2,211' Surface Intermediate 8,835 ' Production 10,159 ' Liner 282' Perforation depth: measured true vedical Size 20" 13 3/8" 9 5/8" 7" 5" B-2 5,124' B-3 5,155' B-3 5,177' Tubing (size, grade, and measured depth) 3 1/2" N-80 e 4,961' Pa ~e[.s..a..,ndc.°~S~y..R.e..a,,,nd~;j'~e,,~s~d~epth) 13. Attachments Description summary of proposal Cemented Measured depth True vertical depth 525 sx 2,000 sx 280' 2,211' 280' 2,211' 1,370 sx 650 sx 41 sx 5,140' MD 5,176' MD 5,197' MD 8,835 15,439 15,697 5,124' - 5,155' - 5,177' - 5,140' TVD 5,176' TVD 5,197' TVD RECEIVED 8,835' 15,439' 15,697' 0 CT - 1 1992 · Detailed ~il Al'lch'omge 14. Estimated date for commencing operatiOn 9/26/92 16. If proposal was verbally approved Name of approver Mike Minder 9/25/92 Date approved 15. Status of well classification as: Oil __ Gas __ Service Class II Suspended __ Disposal 17.1 hereby certify that th(~fo~:g is true and correct to the best of my knowledge. /_ Title Operations Engineering Signed .~ FOR COMMISSION USE ONLY Supv. Date Conditions of approval: Notify Commission so representative may witness Plug integrity __ BOP Test __ Location clearance __ Mechanical Integrity Test __ Subsequent form required 10- ~0~'./ Approved by order of the Commission Form 10-403 Rev 06/15/88 Original Signed By Da,,!d W. Johnston {Approval No. ¢2,~ Commissioner. Date/~ -.,,~-.~'~ PROCEDURE TO PERFORATE BC-2 Prior to E-line, R/U Otis and tag fill with bailer to obtain fill sample and insure no obstructions in tubing or casing. 1) 2) 3) 4) RU E-line. PT lubricator to 1500 psi. Blackout communications, arm 20' of 2-1/8" strip guns, DP 13 g. charges, 0 degree phased, 0 degree offset. 4 SPF. RIH and perforate 5032' - 5052' DIL (new interval). POOH. Arm 21' of same spec. guns. RIH and perforate 5007 - 5028' DIL (also new interval). POOH. 5) Install blanking cap on lubricator. Test injectivity rate at 1500 psi. 6) RD E-line, return BC-2 to injection. 7) Treat with Xylene/acid to improve injectivity if required. H:\wp\WLPRO\BC2 BEAVER CREEK Wireline Lubricator w/Associated BOPE Manually Operated BOP 'Grease Head (Hydrallcally Activated) -- Lubricator Tree *Cap Swab Valve 2' Wing Valve Master Valves 3-1/2' 500.0 Christmas T~ee RECEIVED / Seal Fla~g® OCT - 1 1992 , Alaska Oil & Gas Cons. commissio~ Anchorage Marathon Oil Company Alaska ~,~jion Domestic Production RO. Box 190168 Anchorage, Alaska 99519 Telephone 907/561-5311 December 7, 1988 Alaska Oil & Gas Conservation Commission 3001 Porcupine Dr. Anchorage, AK 99501 Dear Mr. Chatterton: Enclosed is the AOGCC "Report of Sundry Well Operations" with attachments for Beaver Creek Well #2. Should you have any questions regarding the report, please contact me at (907) 561-5311. Sincerely, D. K. Corlett District Operations Engineer Attachment DKC / em/6/ml A subsidiary of USX Corporation STATE OF ALASKA ALA._.,A OIL AND GAS CONSERVATION COMMIS~.ON REPORT OF SUNDRY WELL OPERATIONS Operation shutdown __ Stimulate __ Plugging __ Perforate x_._ Alter casing __ Repair well ~ Pull tubing __ Other __ 91 5. Type of Well: 6. Datum elevation (DF or KB) Development__ 15' KB above GL Exploratory __ Stratigraphic __ 9 19 Service x 1. Operations performed: Pull tubing 2. Name of Operator Marathon Oil Company 3. Address P.O. Box 190168 Anchorage, AK 4. Location of well at surface 590' FNL, 1,979' FEL, At top of productive interval Straight Hole At effective depth Straight Hole At total depth Straight Hole Sec. 3 6N-10W-SM 7. Unit or Property name Beaver Creek Unit 8. Well number BC-2 9. Permit number/approval number 8-765 10. APl number 50--13320021-01 11. Field/Pool Sterling feet 12. Present well condition summary Total depth: measured true vertical 15,697' 15,697' Plugs (measured) Effective depth: measured true vertical Casing Length Structural Conductor 280 ' Surface 2,211 ' Intermediate Production 8,835 ' Liner 10,159 ' 282' Perforation depth: measured true vertical 5,221' feet 5,221 ' feet Size 13 20" 3/8" 5/8" 7" B-2 5,124' B-3 5,155' B-3 5,177' Junk (measured) Cemen~d 525 sx 2,000 sx 1,370 sx 650 sx 41 sx - 5,140' MD - 5,176' MD - 5,197' MD Measured depth 280' 2,211' 8,835' 15,439' 15,697' 5,124' - 5,155' - 5,177' - True vertical depth 280' 2,211' 8,835' 15,439' 15,697' 5,140' TVD 5,176' TVD 5,197' TVD ~bing(size, grade, andmeasuredde~h) 3 1/2" N-80 @ 4,961' Pac~mandSSSV~ypeandmeasuredde~h) Baker FH Packer @ 4,923' 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure RECEIVED 14. Representative Daily Average ProduCtion or Injection Data OiI-Bbl Gas-Md Water-Bbl Casing Pressure Tubing Pressure Prior to well operation S hu t- in Subsequent to operation Shut-in 15. Attachment~ ¢/1 116. Status of well classification as: Copies of Logs and Surveys run ~ I Daily Report of Well Operations .._g.x Oil __ Gas __ Suspended __ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Service Class II Disposa .1 /~- 7- ~'=~'~' Signed ~/~/'f¢_,/3~~ Title District Operations Engineer Form 10-404 Rev 06/15/88 Date 1 2-/"//~C~ SUBMIT IN DUPLICATE Attachment #1 Beaver Creek Well #2 Summary of Daily Operations 10/27/88 RU E-line and PT lubricator to 800 psi w/ N., OK. Made three perforating runs using 2-5/8" through tubing guns, 4 SP~, 0° phasing w/ 11 gm charges. RIH, correlated and perforated Bench 3 from 5177' to 5197' DIL, 5155' to 5176' DIL, and Bench 2 from 5124' to 5140' DIL. POH, RD and SI well. Note: Due to lack of water because of other well work and surface equipment repairs, the proposed injectivity tests could not be conducted at this time. A follow-up report will be sent when these tests have been completed. 45A/BC Marathon Oil Company Alaska ,gion Domestic'Production P.O. Box 190168 Anchorage, Alaska 99519 Telephone 907/561-5311 October 3, 1988 Alaska Oil & Gas Conservation Commission 3001 Porcupine Dr. Anchorage, AK 99501 Dear Mr. Chatterton: Attached for your approval is the Application for Sundry Approval for Beaver Creek Well BC #2. ~~ ~~w~t ~a.~ Should you have any questions regarding any application or report, please contact me at (907) 561-5311. Sincerely, D. K. Corlett District Operations Engineer Attachment DKC/em/6/M1 A subsidiary of USX Corporation STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION' FoR SUNDRY APPROVALS 1. Type of Request: Abandon Suspend . ' Operation Shutdown , } Re-enter suspended well ~ Alter casing ['] Time extension Change approved program Plugging "'~ Stimulate' ; Pull tubing Amend order .r Perforate .~ Other 2 Name of Operator Marathon 0il Com?an7 3 Address P.O. Box 190168 Anchorage, AK 99519 4. Location of well at surface 590' FNL, 1,979' FEL, Sec. 3 6N-10W-SM At top of productive ~nterval Straight Hole At effective depth Straight Hole At total depth Straight Hole 11. Present well condition summary Total depth: measured true vertical 15,697' 15,697' feet Plugs (measured) feet5,221' (cmt & BP) 5,258 ' (BP) 5. Datum elevation (DF or KB) 15' KB above GL feet 6. Unit or Property name Beaver Creek Unit 7. Well numbe.~_.. c-2 8. Permit number 67~26 9. APInumber 50-- 13320021-01 10. Pool 8,400' - 8,715 cmt 11,740' - 11,950' cmt & BP 14,465' - 14,680' cmt & Pkr Effective depth: measured 5,221 ' true vertical 5,221 ' Casing Length Structural Conductor 280 ' Surface 2,211 ' Intermediate Production 8,835 ' 10,159' Liner · 22' Perforation depth: measureo8 true vertical Size feet5,266' feet5,600' Cemented (BP) 14,915' BP (BP) 15,407' CIPB 15,652' - 15 69_7' cmt Measured depth '~rue Vertical depth 20" 525 sx 280' 280' 13 3/8" 2,000 sx 2,211' 2,211' 9 5/8" 1,370 sx 8,835' 8,835' 7" 650 sx 15,439' 15,439' 5" 41 sx 15,697' 15,697' B-2 5,125' - 5,140' MD B-3 5,155' - 5,175' MD B-3 5,177' - 5,197' MD 5,125' - 5,140' TVD 5 155"~-.~5~'L75': 5,177~ ~5.,~I~% ~:T~ Tubing (size, grade and measured depth) 3 1/2" N-80 @ 4,961' Packers and SSSV (type and measured depth) Baker FH Packer @ 4,923' 12.Attachment~ 1 & 2 Description summary of proposal Detailed operations program ffl BOP sketch 13. Estimated date for commencing operation October 1988 14. If proposal was verbally approved Name of approver Date approved 15. I hereby./~ertify that the foregoing is true and correct to the best of my knowledge Signed ~//~TZ ~ Title Region Operations Engineer Commission Use Only Conditions of approval Notify commission so representative may witness I Approval No. EJ Plug integrity [] BOP Test ~ Location clearance~ Approved by ORIGINAL SIGNED BY LONNIE C. SMITH Form 10-403 Rev 12-1-85 Approved Copy Returned i -//- £ Commissioner by order of the commission Date Submit in triplicate Attachment #1 Beaver Creek Well #2 Perforating and Testing Procedure 1. Rig up E-line and pressure test to 2000 psi. 2. RIH and perforate as follows with 2-5/8" guns, 4 SPF, 0° phasing, 11 gm. charges. Run Zone Interval Footage Remarks 1 Sterling B-3 5177' - 5197' 20' 2 Sterling B-3 5155' - 5175' 20' 3 Sterling B-2 5125' - 5140' 15' Tag bottom 3. Attempt to inject filtered lease water into well (surface lines to be flushed with two line volumes of filtered lease water prior to injection). If well will not take at least 2 BPM at less than 2000 psi pump pressure, continue perforating as follows: Run Zone Interval Footage Remarks Upper Sterling 5023' - 5053' 30' Upper Sterling 5004' - 5023' 19' 4970' - 4980' 10' Shoot two zones in single run If well does take required fluid, move on to Step 4. 4. Rig down E-line and RU lease pump unit for injectivity test along with the following equipment: - Tankage to hold 1000 bbls lease water - Rate meter with chart - Pressure recorder with chart table to monitor casing and tubing pressure - Filters to 10 micron nominal or 20 micron absolute 5. Pressure test surface equipment to 2000 psi and perform injectivity test as follows: Rate Time 1BPM 90 min. 2 BPM 30 min. 3 BPM 30 min. 4 BPM 30 min. 6 BPM 30 min. 8 BPM 30 min. Do not exceed test pressure of 2000 psi during test. 6. Rig down pump unit and place well on injection. Note: Maximum anticipated SBHP is estimated to be 1810 psi. NEF/em/45A/BC Attachment #2 BEAVER CREEK Wireline-Lubricator w/Associated BOPE Manually Operated BOP Grease Head (Hydralically Activated) Lubricator ., Tree Cap Swab Valve 2' Wing Valve Master Valve8 4 1/2' 5000 psi Chrlltmae Tree Seal Flange STATE OF ALASKA ALASK~ OIL AND GAS CONSERVATION COMrv, oSlON REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown [] Stimulate ~ Plugging [] Alter Casing [] Other [] 2. Name of Operator Marathon Oil Company 3. Address P.O. Box 190168 Anchorage, AK 4. Location of well at surface 590' FNL, 1,979' FEL, Sec. At top of productive interval Straight Hole At effective depth Straight Hole At total depth Straight Hole 11. Present well condition summary Total depth: measured true vertical 15,697' 15,697' 99519 3 6N-10W-SM Effective depth: measured 5,221 ' true vertical 5,221' Perforate [] Pull tubing [] 5. Datum elevation (DF or KB) 15' KB above GL 6. Unit or Property name Bp~v~ Cr~ TTn~ 7. Well number BC-2 8. Approvalnumber 7-556 9. APInumber 50-- 13320021-01 10. Pool Sterling Casing Length Structural Conductor 280' Surface 2,211 ' Intermediate Production 8,835 ' 10,159' Liner 282' Perforation depth: measured true vertical Feet feet Plugs(measured) 8,400' - 8,715' cmt feet5,22t.-' (Cmt & BP) 11,740' - 11,950' cmt & BP 5,258' (BP) 14,465' - 14,680' cmt & ?kr feet5,266' '(BP) 14,915' BP feet5,600' (BP) 15,407' CIPB 15 6d5e~h ~ue VerticalCa~th Size Cemented Measurea 20" 525 sx 280' 280' 13 3/8" 2,000 sx 2,211' 2,211' 9 5/8" 1,370 sx 8,835' 8,835' 7" 650 sx 15,439' 15,439' 5" 41 sx 15,697' 15,697' B-2 5,125' - 5,140' MD B-3 5,155' - 5,175' MD B-3 5,177' - 5,197' MD ~bing(size, grade and measured depth) 3 1/2" N-80 @ 4,961' Packers and SSSV(type and measured depth) Baker FH Packer @ 4,923' 12. Stimulation or cement squeeze summary See Attachment #1 Intervals treated (measured) 5,125' - 5,140' TVD 5,155' - 5,175' TVD 5,177' - 5,197' TVD 13. Treatment description including volumes used and final pressure Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Prior to well operation 7/14/88 Subsequent to operation 8/30/88 450/24hr. SI 220 Copies of Logs and Surveys Run [] 14. Attachment~: #1 Daily Report of Well Operations [] Tubing Pressure 2000 psi 15. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed Title Region Operations Engineer Form 10-404 Rev. 12-1-85 Submit in Duplicate At t achment # 1 Beaver Creek Well #2 Summary of Daily Operations 8/26/$8 lubricator to 1000 psi w/ N2' RIH w/ 2.55 · ine, pressure tes. t RU w~rel ~ ~ 6' WLM ~n preparation for acid stimulati°n' gauge ring uv ~18 RU C~ and pressure test a~l surface equipment to &000 psi ~et and tag fill 8 5~16' CTM. ~ork CT from 5165' - 5196' C~ while Pump Rate pumping the following: Displacement 1/2 '~PM 1000 gal xylene - 2-hour soak 1500 1/2 BPM 1800 1 / 2 BPM 1000 gal Methanol 2.5 bbls N~4CL (2%) 1790 1/2 BPM Lease Water 1750 3/4 BPM 15 bbls 4-hour soak 1000 gal 7-1/2% NaOC1 - 500 3/4 BPM 10 bbls Lease Water 500 3/4 BPM 15% HCL + additives 0 - Gauge 2000 gal Malfuncti°% 3/4 BPM 2000 gal 12-3 Mud acid + additives ~n~ cn (2%) , 42 bbls 4 Pump down well. Well would not ke more than 1/~ questiOnable due to malfunctiOning ta~ ,.~ 4~,.t- m above are Displacement pressures **°'-d pressure gauge. em/45A/BC Alaska~--'Nstrict Produ¢ .~ United States Marathon Oil Company P.O. Box 102380 Anchorage, Alaska 99510 Telephone 9071561-5311 _ Alaska Oil and Gas Conservation Commission 3001 Porcupine Dear Mr. Wondzell: Report of Sundry Well Operations - Beaver Creek #2 Enclosed is the final Report of Sundry Well Operations for work performed to date on the conversion of Beaver Creek #2 to a Class II disposal well. Included is the daily summary of operations and the results of an R/A tracer and temperature survey performed on July 30, 1987. Also enclosed for your approval is a Sundry Application to acidize the Beaver Creek #2 perforations. This work is planned for the end of this week. Sincerely, D. K. Corlett District Operations Engineer NEF/em/45A/Sundr3 RECEIVED AU. 2 Alaska Oil & Gas Cons. Commission Anchorage / ~. STATE OF ALASKA ~ · ALA~ ,A OIL AND GAS CONSERVATION CO~,-._,dSSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon [] Suspend [] Operation Shutdown [] Re-enter suspended well [] Alter casing [] Time extension [] Change approved program [] Plugging [] Stimulate ~ Pull tubing [] Amend order [] Perforate [] Other [] 2. Name of Operator Marathon Oil Company 3. Address P.O. Box 102380 Anchorage, AK 99510 4. Location of well at surface 590' FNL, 1,979' FEL, Sec. 3 6N-10W-SM 5. Datum elevation (DF or KB) 155 ' KB 6. Unit or Property name Beaver Creek Unit 7. Well number BC-2 feet At top of productive interval Straight Hole At effective depth Straight Hole At total depth Straight Hole 8. Permit number 7-331 9. APl number 50-- 13320021-01 10. Pool Sterling 11. Present well condition summary Total depth: measured true vert!cal 15,697' 15,697' Effective depth: measured 5,221 ' true vertical 5,221 ' Casing Length Structural Conductor 280' Surface 2,211 ' Size 20" 13 3/8" feet Plugs (measured) 8,400' - 8,715' cmt feet5,221' (cmt & BP) 11,740' - 11,950' cmt& BP 5,258' (BP) 14,465' - 14,680' cmt & Pkr feet 5,266" (BP) 14,915' BP feet 5,600' (BP) 15,407' CIPB 15 2' - , Cemented Measur~o6i~epth 15 6917r~e Vertical ~th 525 sx 280' 280' 2,000 sx 2,211' 2,211' Intermediate 8,835 ' Production 10,159' Liner 282' Perforation depth: measured true vertical 9 5/8" 1,370 sx 8,835' 8,835' 7" 650 sx 15,439' 15,439' 5" 41 sx 15,697' 15,697' B-2 5,125' B-3 5,155' B-3 5,177' Tubing(size, grade and measured depth) 3 1/2" N-80 @ 4,961' Packers and SSSV(type and measured depth) Baker FH Packer @ 4,923' 5,140' MD 5,125' - 5,140' TVD 5,175' MD 5,155' - 5,175' TVD AUG 2 0 1987 Alaska 0il & Gas Cons. Commission 12.Attachment~: #1 Description summary of proposal g~ Detailed operations programAI~h0~ sketch [] 13. Estimated date for commencing operation August 1987 14. If proposal was verbally approved Subsequent Work Reported on Name of approver Blair WondzellFormNo. ' ~/~~z~_Datcd?-/~-~/~-~/ Date approved 8/14/87 15. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ~)[(~/c,? (cJ~ TitleDistrict Operations Engineer Date Conditions of approval Approved by Commission Use Only Notify commission so representative may witness I Approval [] Plug integrity [] BOP Test [] Location clearance I ~' ,?% ';~L'; , No. ,~ __.j__,.%._,~ Commissioner by order of the commission Date ~¥"",..~0 Form 10-403 Rev 12-1-85 Submit in triplicate~)_ Attachment # 1 Beaver Creek Well #2 Acid Stimulation - Procedure It is Marathon's intention to perform an acid stimulation to aleviate formation plugging problems in the B-2 and B-3 sands. The procedure is as follows: 1. Prior to acid job, place 5% by volume (20 gal) Howco suds or equivalent in 10 bbls produced water and displace to perfs with 50 bbls with injection pump. SIW. 2. RU service company, test lines. RU pump pressure chart recorder. 3. Pump 20 BW to establish a pump pressure at 2 BPM. Do not exceed 2,000 psi pump pressure at any time. 4. Pump 1,000 gallons 15% HC1 plus additives at 2 BPM. After 1/2 of acid is displaced at 2 BPM, SD for 15 minutes. Displace remaining acid at 1/2 BPM. 5. Pump 10 bbls of gelled (30#/1,000 gal) produced water containing 500 lbs of high grade rock salt diverter at 2 BPM. 6. Follow diverter with 1,000 gallons 15% HC1 plus additives. Displace 1/2 acid at 1/2 BPM. SD for 15 minutes. Displace remaining acid at 1/2 BPM. Total displacement = 58 bbls. 7. Overflush treatment with 100 bbls of produced fluid at 3-4 BPM, not exceeding 2,000 psi. 8. Return well to injection as soon as possible. NEF/em/45A/Sundr3 RECEIVED AUG. 2 0 - 987 ~aska 0i, a L~ES C.0~s. C0m~issi0n Anchorage Marathon Oil Company ,.~ Alask, ~strict Produc,,,.,n United States P.O. Box 102380 Anchorage, Alaska 99510 TelephOne 907/561-5311 August 19, 1987 Mr. Blair Wondzell Alaska Oil and Gas Conservation Commission 3001 Porcupine Anchorage, AK 99510 Dear Mr. Wondzell: Report of Sundry Well Operations - Beaver Creek #2 Enclosed is the final Report of Sundry Well Operations for work performed to date on the conversion of Beaver Creek #2 to a Class II disposal well. Included is the daily summary of operations and the results of an R/A tracer and temperature survey performed on July 30, 1987. Also enclOsed for your approval is a Sundry Application to acidize the Beaver Creek #2 perforations. This work is planned for the end of this week. Sincerely, D. K. Corlett District Operations Engineer NEF/em/45A/Sundr3 RECEIVED ALJG 2 0 ~aska Oil & Gas Cons. Commission ...... _Anchorage STATE OF ALASKA AL/-,_ ~,A OIL AND GAS CONSERVATION CO, .... ,ISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown [] Stimulate [] Plugging [] Perforate [] Pull tubing [] Alter Casing [] Other I~ Converted to Class II Disposal Well 2. Name of Operator Marathon Oil Company 3. Address P.O. Box 102380 Anchorage, AK 99510 4. Location of well at surface 590' FNL, 1,979' FEL, Sec. 3 6N-10W-SM 5. Datum elevation (DF or KB) 155' KB 6. Unit or Property name Beaver Creek Unit 7. Well number BC-2 At top of productive interval Straight Hole At effective depth Straight Hole At total depth Straight Hole 8. Approvalnumber 7-331 ,, , 9. APInumber 50-- 13320021-01 10. Pool Sterling Feet 11. Present well condition summary Total depth: measured true vertical 15,697' 15,697' feet feet Effective depth: measured 5,22-1 ' true vertical 5,221 ' feet feet Casing Length Size Structural Conductor 280 ' 20" Surface 2,211' 13 3/8" Intermediate 8,835' 9 5/8" Production 10,159' 7" Liner 282' 5" Perforation depth: measured true vertical B-2 5,125' - B-3 5,155' - B-3 5,177' - Tubing(size, grade and measured depth) 3 1/2" N-80 @ 4,961' Packers and SSSV(type and measured depth) Baker FH Packer @ 4,923' Plugs(measured) 8,400' - 8,715' cmt 5,2,21' (cmt & BP) 11,740' - 11,950' cmt & BP 5,258' (BP) 14,465' - 14,680' cmt & Pkr 5,266' (BP) 14,915' BP 5,600' (BP) 15,407' CIPB 15,652' - 15 697' cmt Cemented Measured depth ' ~ue Verticaldepth 525 sx 280' 280' 2,000 sx 2,211' 2,211' 1,370 sx 650 sx 41 sx 5,140' MD 5,175' MD 5,197' MD 8,835' 15,439' 15,697' 5,125' - 5,155' - 5,177' - 5,140' TVD 5,175' TVD 5,197' TVD 8,835' 15,439' 15,697' RECEIVED 12. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure AUG 2 o 198'i Oil & Gas Cons. 6ommissio. Anchorage 13. Prior to well operation Subsequent to operation Representative Daily Average I~rm~xa~izm~mxlnjection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 300 700 psi 14. Attachment~ ¢~1 Daily Report of Well Operations Copies of Logs and Surveys Run ~femp. Log 15. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ~/~fcz7 ~ ~-- Title District Operations Engineer Form 10-404 Rev. 12-1-85 Date g/I ~/8"/ Submit in Duplicate Attachment #1 Beaver Creek Well #2 Daily Summary of Well Operations 7~30~87 RU for injection survey. Run injection pump and stabilize injection @ 640 psi, 22 BPH (528 BWIPD) based on tank gauge. RIH w/tracer and temperature tool. Tag bottom @ 5,195' DIL correlated to production log run on 12/14/83. Found no leaks in circulating sleeve or packer w/radioactive tracer. Logging results as follows: Interval % Injection BWIPD Stop at 5,188', 7' off bottom B-3 5,188' - 5,195' 5,170' - 5,188' 5,149' - 5,170' 63% 333 12% 63 12% 63 B-2 5,125' - 5,140' Tracer indicates 556 BWIPD. 13% 69 528 Tank gauge indicates 528 BWIPD. Run dynamic temp pass approximately 76°F at bottom while injecting. Formation temp should be approximately 100°F. SIW - wait for static temp pass. Ran 1 hr., 2 hr., and 3 hr. static temp. passes to determine intervals taking fluid. POOH & RD. Place well on injection. NEF/em/45A/Sundr3 RECEIVED AUG 2 0 ~aska Oil & Gas Cons. Commi$,sion Anchorage Marathon Oil Company Alask~ ,,rict ProducL,,.,,~ United States RO. Box 102380 Anchorage, Alaska 99510 Telephone 907/561-5311 July 9, 1987 Blair Wondzell Alaska Oil and Gas Conservation Commission 3001 Porcupine Anchorage, AK 99510 Dear Mr. Wondzell: Report of Sundry Well Operations - Beaver Creek #2 Attached is the Report of Sundry Well Operations for Beaver Creek #2. Included is the daily summary of operations, casing integrity and injectivity test chart, and a plot of the injectivity test results. Sincerely, D. K. Corlett District Operations Engineer NEF/em/45A/Sundr3 RECEIVED JUL 1 ~ 1987 Alaska Oil A Gas Cons. Commission Anchorage /'-'",. STATE OF ALASKA ~ ALA ..... OIL AND GAS CONSERVATION CON .... 5SlON REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown [] Stimulate [] Plugging [] Perforate [] Pull tubing [] Alter Casing [] Other [] Converted to Class II Disposal Well 2. Name of Operator Marathon Oil Company 3. Address P.O. Box 102380 Anchorage, AK 99510 4. Location of well at surface 590' FNL, 1,979' FEL, Sec. 3 6N-10W-SM At top of productive interval Straight Hole At effective depth Straight Hole At total depth Straight Hole 5. Datum elevation (DF or KB) 155' KB 6. Unit or Property name Beaver Creek Unit 7. Well number BC-2 8. Approval number 7-331 9. APl number 50-- 13320021-01 10. Pool Sterling Feet 11. Present well condition summary Total depth: measured true vertical 15,697' 15,697' Effective depth: measured 5,221 ' true vertical 5,221 ' Casing Length Structural Conductor 280 ' Surfa~ce 2,211 ' Intermediate 8,835 ' Production 10,159' Liner 282' Perforation depth: measured true vertical Size 20" 13 3/8" 9 5/8" 7" 5'7 feet Plugs (measured) 8,400' - 8,715' cmt feet5,221' (cmt & BP) 11,740' - 11,950' cmt & BP 5,258' (BP) 14,465' - 14,680' cmt & Pkr feet5,266' (BP) 14,915' BP feet5,600' (BP) 15,407' CIPB 5 2 ' - 5 cmt Cemented Meas]rdr~a6~epth i , 69-~r'ue Vertical depth B-2 5,125' B-3 5,155' B-3 5,177' 525 sx 280' 280' 2,000 sx 2,211' 2,211' 1,370 sx 650 sx 41 sx - 5,140' MD - 5,175' MD - 5,197' MD 8,835' 8,835' 15,439' 15,439' 15,697' 15,697' 5,125' - 5,140' TVD 5,155' - 5,175' TVD 5,177' - 5,197' TVD Tubing(size, grade and measured depth) 3 1/2" N-80 @ 4,961' Packers and SSSV(type and measured depth) Baker FH Packer @ 4,923' RECEIVED 12. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure JUL 1 1987 Alaska 0il & Gas Cons. Commission Anchorage 13. Prior to well operation Subsequent to operation Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure See attached step rate test Disposal to commence later this week 14. Attachmentm#2 Casing Integrity & Step Rate Test Chart, Attach. #3 Step Rate Test Results Attach, #1 Daily Report of Well Operations [] Copies of Logs and Surveys Run [] 15.1 hereby certify that the foregoing is true and correct to the best of my knowledge ~ ~"-//~'"-~"~ Signed ~)~~ ~ ~ District Operations Engineer Title Date '~/c~/87 Form 10-404 Rev. 12-1-85 Submit in Duplicate Attachment #1 Beaver Creek Well #2 Daily Summary of Well Operations 613187 RU CTU. RIH w/coil tubing w/wash nozzle, filled hole to surface. Tagged fill @5,210' CTM. Wash fill while circ @ 1.24 BPM w/20#/1000 gal HEC polymer. Washed to 5,229'. POH to 5,200' - could not work back past 5,221' CTM on several attempts. Pump sweep - hole clean - filled hole with produced water and POH. RD CTU. 6112187 RU - Make up 20' gun, pressure test to 1,500 psi, OK. RIH, correlate (17' deep). Tag fill @ 5,197'+ DIL. Perforate B-3 5,177' - 5,197' (MD) w/4 SPF - 2-5/8" hollow carrier llgm charges. POH. Make up gun and pressure test. RIH, correlate (8' shallow). Perforate B-3, 5,155' - 5,175' MD)- POH and RD. 6/25/87 RU pump truck and prepare for injectivity test. Pressure test tubing/casing annulus to 1,500 psi for 35 minutes - tested good. Corrosion inhibited fluid used to fill annulus (0.75% KW132) - 1 bbl pumped. Run inj ectivity tests. RD. 6/26/87- 715187 Well took 4576 barrels of produced water by gravity flow over this 10-day period (458 BWPD average). NEF/em/45A/Sundr3 RECEIVED JUL ! 5 1987 ,Alaska Oil & 6as Cons. Commission Anchoraoe Casing~.Inte: Attachment ;rity & Injectivity Test Chart )OC ~o ~t,. I F. .S.A. o o~ s~nOH / O~ &An~c~o%ohs- Commission ge '2400-- 2300 - 2200 -~ 2100 ~ 2000 -- 1900 - 1800 - 1700 - 1600- 1500 - 1400 -- 1300 -- 1200 - t100 - 1000 -- 900-- 800 - 700 - 600 -- 5010 - 400 - 300 - 200 -- 100 - 0 4000 3900 3800 3700 3600 3500 3400 3300 3200 3100 3000 2900 2800 2700 2600 2500 --- Attachment #.3_ .~--~.Injectivity Test Results · = 1st injection test ® = 2nd injection test / -BPM Pressure BPM 1 600 1 2 1250 2 3 1500 - 600 3 "/ 4 1000 / 6 1600 6 8 2300 Pressure 5OO 700 1100 1800 · I '" 'I' ''1' I ....i ......... 1 ....... r' I i '-~ ~ ':'~ 1 2 3 4 5 6 7 8 9 10 BPM - INJECTION RATE (est) Rate (BPM) Pf ~PH 22 2300 78 2300 166 2300 282 2300 598 2300 1018 2300 RECEIVED JUL 1 3 1987 ' Alaska Oil & Gas Cons; Commission Anchorage Ps BHP 500 2778 700 2922 1100 3234 1000 3018 1600 3302 2300 3582. ~PH = 8.34 (1.02)(.052) x 5200' : 2300 psi Pf = h(psi) = 4961 (2.26 ,,GPM ~.852 100 (2.992)2~63 BHP = Ps - Pf +~PH Marathon Oil Company May 21, 1987 Alaska ., ict Producbun United States RO. Box 102380 Anchorage, Alaska 99510 Telephone 907/561-5311 Alaska Oil & Gas Conservation Commission 3001 Porcupine Dr. Anchorage, AK 99501 Gentlemen: In reviewing our records I find that a Report of Sundry Well Operations for Marathon's Beaver Creek #2 was not submitted for workover operations, which commenced on January 9, 1987, and ended on February 19, 1987, state approval No. 485. The attached report should bring your records for this well up to date and we apologize for the oversight. S incer ely, D. K. Corlett District Operations Engineer cc: NEF NEF/em/45A/Sundr3 RECEIVED Alaska 0il & Gas Cons. CommJssio~ Anchcr~a STATE OF ALASKA ~ ALAb..,-~ OIL AND GAS CONSERVATION CON, ,SSlON REPORT OF SUNDRY WELL OPERATIONS 1. OperatiOns performed: Operation shutdown [] Stimulate [] Plugging [] Perforate [] Pull tubing [] Alter Casing [] Other [] 2. Name of Operator Marathon Oil Company 3. Address P.O. Box 102380 Anchorage, AK 99510 4. Location of well at surface 590' FNL, 1,979' FEL, Sec. 3 6N-10W-SM 5. Datum elevation (DF or KB) 155' KB 6. Unit or Property name l~eaver Creek Unit 7. Well number BC-2 At top of productive interval Straight Hole At effective depth Straight Hole At total depth Straight Hole 8. Approval number 485 9. APl number 50-- 13320021-01 10. Pool Sterling Feet 11. Present well condition summary Total depth: measured true vertical 15,697' 15,697' Effective depth: measured 5,221 ' true vertical 5,221' Casing Length Size Structural Conductor 280' 20" Surface 2,211' 13 3/8" Intermediate 8,835' 9 5/8" Production 10,159' 7" Liner 282' 5" Perforation depth: measured true vertical feet Plugs (measured) 8,400' - 8,715' cmt feet 5,221' (cmt & BP) 11,740' - 11,950' cmt & BP 5,258' (BP) 14,465' - 11,680' cmt & pkr feet 5,266' (BP) 14,915' BP feet 5,600' (BP) 15,407' CIBP Cemented Measure~J crop'Ih ' ~r~7e'Vertical 525 sx 280' 280' 2,000 sx 2,211' 2,211' B-2 5,125' B-3 5,155' 1,370 sx 8,835' 8,835' 650 sx 15,439' 15,439' 41 sx 15,697' 15,697' - 5,140' MD 5,125' - 5,140' TVD - 5,220' MD 5,155' - 5,220' TVD Squeezed ~bing(size, grade and measured depth) 3 1/2" N-80 @ 4,961' Packers and SSSV(type and measured depth) Baker FH Packer @ 4,923' 12. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure 13. Prior to well operation Subsequent to operation Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 2/19/87 Shut-in 14. Attachment~: #1 & 2 Daily Report of Well Operations [] Copies of Logs and Surveys Run [] 15. I hereby certify that the foregoing is true and correct to the best of my knowledge ~ / ~ Signed /,~'Co'~. ~, ~ Title District Operations Engineer Date ~'/21/~--~ Form 10-404 Rev. 12-1-85 Submit in Duplicate Attachment 1 Beaver Creek Well #2 Daily Summary of Well Operations 119187 RU CTU. Mix 220 bbls HEC polymer. RIH w/ wash nozzle on 1-1/4" coil tbg. Circ 1-1/4 - 1-1/2 BPM. Tag bridge @ 5,156' CTM. Wash bridge to retainer @ 5,223' CTM. Circ & move CT from retainer to tbg tail four times to clean hole. 1/10/87 RIH jetting with N~ to 2,200' - continue to jet. Returns of H^O and N2. Recovered 81 bbls ~2© in two hours - little or no gas. RIH toZ3,000' and · jet w/N9 - some gas mn returns - jetted for 1 hour. S/D N2. POH w/CT - well died in 45 minutes. Recovered ±60 bbls H20. 1115187 RIH w/CT. Circ 1/4 BPM to 5,100' CTM. S/D pumping. RIH and tag at retainer - no fill. POH to 4,900' CTM and flag coil @ tubing tail. Conduct injectivity test down tubing & coil annulus. Rate Pressure Vol. In~. 1/2 BPM (720 B/D) 1 B?M (1440 B/D) 1.5 BPM (2160 B/D) 2.0 BPM (2880 B/D) 250 psi 10 bbl 350 psi 10 bbl 550 psi 40 bbl 600 psi 15 b~ POH w/ coil tubing. 1/16/87 '~*"'--~ Oil & Gas RIH & circ 7-1/2 BPM. Tagged retainer ~ 5,246' C~ - no fill. Mi~e'~~' contaminent (30 bbl borax & bentonite) ~ 13 bbl cement slurry & properties of cement - 36 cc fluid loss ~ 1,000 psi, 80~ for 30 min. Pressured to 1,000 psi and held solid for 40 min. Cleaned out and circ contaminent. POH. 1/17/87 RIH w/2-1/2" cement nozzle pumping 1/2 - 2-1/2 BPM. Cleaned contaminated cement out to retainer @ 5,239' CTM. Circ bottoms up and pumped four thick HEC polymer sweeps. Washed from PBTD to the tubing tail. RIH to PBTD, circ polymer sweep. Returns were clean. POH to 2,000'. Blew well dry w/N2. POH. 1118187 RIH. Perf B-2 sand 5,125' - 5,140' DIL w/2-1/8" enerjets, 4 SPF, 0° phasing. POH. Pressure test to 2,000 psi. RIH. Perf B-2 sand 5,125' - 5,140' DIL w/2-1/8" enerjets, 4 SPF, 90° phasing. POH. RD wireline. 1119187 RIH to 2,500'. Circ 300 CFM N~ - unload water and well continued to flow @ 80 psi through 32/64 choke. R~H to 2,900' Circ N2. POH w/coil tubing. RD - continued to flow w/well unloading some water. Final pressure was 1,170 psi w/17/64 choke and well appeared to be cleaning up. S.I. well. 1120187 Attempted flow test. Had ice plug between heater and separator. 1/21/87 Thawed out lines between line heater & separator. Removed choke on separator and repaired. Repaired gas regulator on line heater. Tried to bring on well, no success. 1/22/87 Well barely flowing - unloaded 69 bbls water in 10 hours. Shut in #6 sales 1/2 hour to raise gas lift pressure. 1/23/87 Unloaded 189 bbls water from well. Shut in until further notice. 2/9/87 RIH w/CT & tag fill @ 5,210 CTM. Clean out fill (29') to 5,239' CTM. Circ well clean w/visc HEC partial returns. POH to 5,000' RIH - no fill tag @ 5,221'. Mix 17+ bbl cement ±38 bbls, 20#/bbl borax, ±10#/bbl bentonite contaminent - 1,000 psi. Perform CT squeeze. Squeezed w/2-1/2 bbl to 1,220 psi @ 4,950' while squeezing @ 1/4 BPM. Bled pressure to 500 psi and circ contaminent @ 3/4 BPM. RIH w/CT to 4,950' - 5,221' & POH while circ contaminent. 2/10/87 RIH and circ. Tag @ 5,221' - circ hole clean w/produced water. Run in & out of hole to clean casing. Returns clean. Pressure test squeeze to 1,200 psi for 15 min. POH w/CT. S.I. well. 2/17/87 RU CTU and N2. RIH w/CT fitting w/250 CFM to 2,300' - jet @ 2,300' for 10 min. POH. 2/18/87 RU wireline. RIH to 2,500'. Perforate B-2 sand 5,125' - 5,140' DIL w/4 SPF, 2-1/8" silver jets, 0° phasing. POH. RD wireline. RU CTU. RIH, jetting w/N? from 1,500' - 2,000'. Jetted well two times @ 2,000' and then shut down N~ - well died both times. Jetted well two times @ 2,500' - well died both t~mes. POH w/CT. 2/19/87 RIH w/CT to 1,300'. Started jetting with N?. RIH to 2,500' jetting. Shut off N2 to let well flow. Well died. Jette~ with N2 to 3,000'. Shut off N2 to let well flow. Well flowing small amount of gas and N2 and slugging water. TP = 50 psi. RIH wCT to 3,500', jet w/N2 @ 250 SCFM. TP = 200 psi. Shut off N~ to let well flow. Well flowing water, gas and N~. TP = 50 psi. Jettin~ w/N2 from 3,500', 250 SCFM. TP from 50 psi to z 200 psi in 15 min. Shut off N?, TP from 200 psi to 50 psi in 15 min. Monitor well. POOH w/CT. WelI flowing into tank. Daily rate of 1,080 BWPD. Monitor well TP = 25 psi, well still flowing water, some gas. Shut in well. NEF/em/45A/Sundr3 12__-;),'"8". 72&68// N-80 and ~ J-55 to 2211 ' Attachment #2 6EAVER CREEK #2 WELLBORE SCHEHATIC (Currently Shut-in 2/19/87) 5221 ' DIL ~:. ~.-. ~ .7~ 5258' DIL (5270' OPM) 5268' DIL (5280' DPM) 85~4~ .. o 9-5/8", 43.5// N-80 ~ 8rd csg _ . Bkr "K" rtnr Bkr minK" rtnr Top 7" lnr stub ~' lnr tie back slv '9"5/8", 40, 49.5 s 47#, N-80 & S-95 csg to 8835' L 5" lnr top 15,415' 7". 32 . ,-8o, P-])o to 15,439 5" 185 FJ Uydril~lS,69_7_[ Depth 483' . . ID 2.75" 3- I/2" 9.2# q889' 4923' 2.75" 3.O0" 4961' 3.00" PERFORATIONS (DIL) 5,125' - 5,140' B-2 ClW 'DC-FB8' tbg hgr (3-1/2 EUE 8rd b x t) Ported for !/4" control line Otis 'XL' Ball valve nipple (3-1/2" Butt pxb) · But~, N-80 tbg Otis XA circ sleeve (3-1/2" butt p x b) Bkr FH hyd pkr (3-1/2" butt p x b) Bkr WL entry guide 5155'-5220' B-3 2 HPF Squeezed 5230'-5244' B-3A 2 HPF 5263'-5265' 5266' OIL 5296' OPM 5324'-5344' 5600' 6500' 8400;-8715' 11,740I 11¥950' 14,465' 14,680' 14,915' 15,407' 15,652' 15,697' Squeeze perfs Bkr "N" BP B0T hyd pkr _ 2 HPF (perfd in error) Baker BP Ann cmt top Cmt in 7" lnr Cmt top Baker B~.~ Cmt top Bkr FB-I Perm pkr w/ Q nipple & blanking plug ~kr "N" Bp Howco 7" Drillable CIBP PBTD TD NEF 5/14/87 Marathon Oil Company May 12, 1987 Alaskarl ~trict Production United States RO. Box 102380 Anchorage, Alaska 99510 Telephone 907/561-5311 Mr. Chat Chatterton AOGCC 3001 Porcupine Drive Anchorage, AK 99507 RE: UNDERGROUND INJECTION BEAVER CREEK FIELD KENAI, AK Pursuant to your recent telephone request, attached is a sundry notice for the conversion of BC%2 from a producer to an injection well. Should you have any questions please contact me at 564-6316. R. BROOKS THOMAS ENVIRONMENTAL & SAFETY SUPERVISOR mrh ES5:43 RECEIVED Alaska 0il & Gas Cons. L;~mmissior~ Anchorage - '~"'"'~ STATE OF ALASKA ALASK,-, OIL AND GAS CONSERVATION COMk. .,SION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon [] Suspend [] Operation Shutdown [] Re-enter suspended well [] Alter casing [] Time extension [] Change approved program [] Plugging [] Stimulate [] Pull tubing [] Amend order [] Perforate [~ Other [] 2. Name of Operator Marathon Oil Company 3. Address P.O. Box 102380 Anchorage, AK 99510 4. Location of well at surface 590' FNL, 1,979' FEL, Sec. 3 6N-10W-SM 5. Datum elevation (DF or KB) 155 ' KB 6. Unit or Property name Beaver Creek Unit 7. Well number BC-2 At top of productive interval Straight Hole At effective depth Straight Hole At total depth Straight Hole 8. Permit number 67-26 9. APl number 50-- 13320021-01 10. Pool Sterling feet 11. Present well condition summary Total depth: measured true vertical 15,697' 15,697' Effective depth: measured 5,221 ' true vertical 5,221 ' Casing Length Structural Conductor 280' Surface 2,211 ' Intermediate Production 8,835 ' Liner 10,159 ' Perforation depth: measure?¢~2' true vertical Size feet Plugs (measured) 8,400' - 8,715' cmt feet 5,221' (cmt & BP)il,740' - 11,950' cmt & BP 5,258' (Bp)14,465' - 14,680' cmt & Pkr feet 5,266' (BP) 14,915' BP feet 5,600' (BP) 15,407' CIPB 5 I , v Cemented Measlu-5r~(~ 5d~pth- 15 6 9:~rue Vertical c~ 20" 13 3/8" 525 sx 280' 280' 2,000 sx 2,211' 2,211' 9 5/8" 1,370 sx 7" 650 sx 5" 41 sx B-2 5,125' - 5,140' MD B-3 5,155' - 5,220' MD Tubing(size, grade and measured depth) 3 1/2" N-80 @ 4,961' Packers and SSSV(type and measured depth) Baker FH Packer @ 4,923' 12.Attachments #1 & 2Description summary of proposal 8,835' 8,835' 15,439' 15,439' 15,697' 15,697' 5,125' - 5,140' TVD 5,155' - 5,220' TVD Squeezed RECEIVED Alugka 0il & o.~ Cons. C0rnmissi0n Detailed operations program ~w;h~'([]rl~, sketch [] 13. Estimated date for commencing operation June, 1987 14. If proposal was verbally approved Name of approver Date approved 15. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed /.~)~o7~/~/'-'-- Title District Operations Engineer Date Commission Use Only Conditions of approval Notify commission so representative may witness Approval No. [] Plug integrity [] BOP Test [] Location clearance '7 "'- "~' ...... - ...... ' Commissioner the commission Date Approved by g] I..~gl[ t. ,~11~ Form 10-403 Rev 12-1-85 Submit in triplicate Attachment #2 - 20", 9h# H-40 to'280' 12--~/8". 72&68# N-80 and., J'55 to 2211' 9-5/8", 43.5// N-80 ~ 8rd csg Bkr "K" rtnr Bkr "K" rtnr Top 7" lnr stub 7" inr tie back slv 8594I ~-5/8", 40, 4:~.~ ~ 47//, . N-80 & S-95 csg to 8835' BEAVER CREEK //2 WELLBORE SCHEMATIC (Currently Shut-in 2/19/87) j' Depth .: 483' 5221 ' DIL (5233' DPM) ,,-,, 5258' DIL (5270' DPM) 5268' D! L I (5280' DPM) -. 5" lnr top 15,415' 7", 2~ & 32#, N-80 & P-Il0 ~i i" " to 15,439' ' [ . .~ ID 2.75" ~-1/2" 9.2// 4889' 2.75" 4923' 3.00" 4961' 3.00" PERFORATIONS (OIL) 5,125' - 5,140' B-2 5155'-5220' Squeezed CIW 'DC-FBS' tbg hgr (3-1/2 EUE 8rd b x t) Ported for l/q" control line Otis 'XL' Ball valve nipple (3-I/2" Butt p x b) · But~, N-80 tbg Otis XA circ sleeve (3-t/2" butt p x b) Bkr FH hyd pkr (3-1/2" butt p x b) Bkr WL entry guide 2 HPF 5230'-5244' B-3A 2 HPF 5263'-5265' 5266' DIL 5296' DPM 5324'-5344' 5600' 6500' 8400'-8715' !1,740' 11,950' B-4 14,465' 14,680' 14,915' 15,407' 15,652' 15,697' Squeeze perfs Bkr "N" BP BOT hyd pkr 2 HPF (perfd in error) Baker BP 'Ann cmt top Cmt i n 7" 1 nr · ~ · Cmt top Baker BP~..~. RECEIVED - ~ Oi~ & Gas ,',¢, , uut18. Anchorage Cmt top Bkr FB-1 Perm pkr w/ Q nipple & ~lanking plug ~kr "N" Bp Howco 7" Drillable ClBP PBTD TD NEF 5/14/87 Attachment #1 Beaver Creek #2 Conversion to Injection Procedure It is Marathon's intention to convert Beaver Creek Well #2 to a Class II disposal well beginning June, 1987. Beaver Creek #2 will be cleaned out and reperforated in the Sterling B-2 and B-3 sands. The procedure follows: 1. Rig up CTU. Clean out fill to retainer at 5,221' DIL. 2. Pressure test 9-5/8" x 3-1/2" annulus to 1,500 psi for 30 min. Rig down CTU. 3. Rig up E-line. Perforate the B-3 sand from 5,220' - 5,155' DIL with 8 HPF. Reperforate the B-2 sand from 5,140' - 5,125' DIL with 4 HPF. Rig down E-line. 4. Perform step rate injection test varying injection pressures to a maximum of 2,000 psi. 5. Run temperature survey to determine that injection water is staying in zone. 6. Initial injection is expected to be less than 1,000 bpd, dependent on daily volume of produced water, at average injection pressures of 500 - 700 psi. NEF/em/45/OE20 Marathon Oil Company May 12, 1987 Alask . ..~trict Produ(~.on United States GO.MM -~OM M~ RO. Box 102380 Anchorage, Alaska 99510 Telephone 907/561-5311 '~e E.N. Mr. Joe Dygas Bureau of Land Management 4700 East 72nd Avenue Anchorage, AK 99507 RE: UNDERGROUND INJECTION BEAVER CREEK FIELD " KENAI, AK Pursuant to our recent telephone conversation, attached is a sundry notice and permit application for the conversion of BC92 from a producer to an injection well. Should you have any questions please contact me at 564-6316. THOMAS R. BROOKS ENVIRONMENTAL & SAFETY SUPERVISOR mrh ES5:43 cc:./Chat Chatterton Bob Riche¥ RECEIVED Alaska Oil & Gas Cons. Commission Anchorage ~I~ 3160-5 ~.~'oSember 1983) (Formerly 9--331) U N ITED STATES susmT I~ TmP~.ICAT--.' (Other Instructions on re- DEPARTM~ Of THE INTERIOR ,erse~lde) /,.-"'~\ BUREAU~ [ LAND~ANAGEMENT SUNDRY NOTICES AND REPORTS ON WELLS (Do not use this form for proposals to drill or to deepen or plug back to a dl~erent reservoir. Use "APPLICATION FOR PERMIT--" for such propo~ls.) om [-] CAS [] WELL wr. LL OTHER 2. NAIdE OF OPERATOR Marathon 0il Company ADDRESS OF OPERATOR P. O. Box 102380 Anchorage, AK 99510 I,OCATION OF WELL (Report location clearly and in accordance with any State requirements.* See also space 17 below.) At surface 590' FNL and 1,979' FEL Sec. 3, T6N, R10W, SM 14. PERMIT NO. State 67-26 15. ELEVATIONS (Show whether nF, aT, OR, etc.) 155 ' KB l~udget l~ureau Ho. 1004--0135 Expires. August 31, 1985 ~. LEASE DESIGNATION AND SERIAL NO. A-028118 6. IF INDIAN, ALLOTTEE OB TRIB~ NAME 7. UNIT AGREEMENT NA~IE Beaver Creek Unit 8. F~M OR LEASE NAME Beaver Creek 9. WIlL NO. BC #2 10. FIELD AND POOL~ OR WILDCAT Beaver Creek - Sterling 11. aEC., T., ~a., M., OK BL~'. AND Buivmy OR AREA Sec. 3, T6N, R10W, SM 12. COUNTY OR P~alSa] 13. ISTATE Kena± Pen±n.I AK 1C. Check Appropriate Box To Indicate Nature o[ Notice, Report, or Other Data FRACTURE TREAT SHOOT ~ REPAIR WELL (Other) NOTICE OF INTENTION TO : L.-----J CHANGE PLANS Convert to injectio .l~_i WATER SHUT-Ore 1,~ aEPlza!~o WEL~ FRACTURE TREATMENT ALTERING CASING (Other) (NOTE: Report results of multiple completion on Well Completion or Recompletion Report and I~g form.) 17. V};SCRZBE PROPOS£V OR COMPLETED OPERATIONS (Clearly state all pertinent details, and give pertinent dates, including estimated date of 8tsrtlng any proposed work. If well i~ directionally drilled, give subsurface locations and measured and true vertical depths for all markers and zones perti- nent to this work.) * It is Marathon's intention to convert Beaver Creek Well #2 to a Class II disposal well beginning June, 1987. Beaver Creek #2 will be cleaned out and reperforated in the Sterling B-2 and B-3 sands. The procedure follows: 1. Rig up CTU. Clean out fill to retainer at 5,221' DIL. 2. Pressure test 9-5/8" x 3-1/2" annulus to 1,500 psi for 30 min. Rig down CTU. 3. Rig up E-line. Perforate the B-3 sand from 5,220' - 5,155' DIL with 8 HPF. Reperforate the B-2 sand from 5,140' - 5,125' DIL with 4 HPF. Rig down E-line. 4. Perform step rate injection test varying injection pressures to a maximum of 2,000 psi. 5. Run temperature survey to determine that injection water is staYing in zone. 6. Initial injedtion is expected to be less than 1,000 bpd, dependent on daily volume of produced water, at average injection pressures of 500 - 700 psi. 18. I hereby certffy/~.hat, the foregol~u~ is true and correct SIGNED ~/(~ ~ ~-~ TITLE District Operations Engr. DATE 5/12/87 (This space for Federal or State office use) APPROVED BY CONDITIONS OF APPROVAL, IF AtxrY: TITLE *See Instructions on Reverse Side Alaska 0il & Gas Cons, Commission . Anch0raq0 Title 18 U.S.C. Section !001, makes it a Crime for an5' person knowingly and willfully to make to an5' oeparrment Or agency of the United States an5' faire, fictitious or fraudulent statements or representations as to any matter within its jurisdiction. Marathon Oil Company Alaskar~~t Produc united States P.O. Box 102380 Anchorage, Alaska 99510 Telephone 907/561-5311 May 12, 1987 Bob Richey Kenai National Wildlife Refuge P.O. Box 2139 Soldotna, AK 99669 RE: -. UNDERGROUND INJECTION BEAVER CREEK FIELD KENAI PENINSULA, AK. Pursuant to our recent telephone conversation, attached is a drawing describing the proposed surface facilities for the conversion of BC92 from production to injection. It is proposed to install surface facilities consisting of two-500 gallon tanks, one triplex pump, one shelter and associated piping. All work can be performed on the existing pad. Should you find the proposal acceptable, please indicate so by signing the approval line below and returning the original in the envelope provided. If you have any questions please don't hesitate to contact me at 564-6316. THOMAS R. BROOKS ENVIRONMENTAL & SAFETY SUPERVISOR Approved Date cc: %~hat Chatterton Joe Dygas Alaska Oil & Gas Con:..:.~;o,, Anchorage B'~AVER- CREEK ~2 I-AD o T-PACK -. BEAVER CR.~2 TRIPLEX PUMP SHELTER 200' 500 GAL. TANKS SCALE: Gas Co~s. ColD~.-,~ · Marathon Oil Company May 4, 1987 Doyle L.~ Productk ~ger Alaskan I:: Production ,.,nited Siates P.O. Box 102380 Anchorage, Alaska 99510 Telephone 9071561-5311 Mr. C. V. Chatterton, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 RE: UNDERGROUND INJECTION BEAVER CREEK FIELD KENAI PENINSULA, ALASKA Marathon Oil Company, as operator of Beaver Creek Field, requests that an injection order be issued to authorize the conversion of BC~2 from'a producer to a Class II disposal well. The wastes proposed for injection consist of nonhazardous waste fluids generated during normal drilling, workover and production operations. The proposed injection depth would be those zones suitable for injection 50 feet below the 13 3/8" (2211') casing or below 2261'. Injection into BC#2 will be accomplished in two phases. In Phase I, it is proposed to inject into existing perforations open in the Sterling B-2 gas sands from 5125'-5140'and proposed perforations reopening the Sterling B-3 gas sands from 5155-5220'. These sands watered out in early 1987. Phase II would be initiated after Phase I is complete. In Phase II, it is proposed to abandon the perforations from Phase I and inject into the Sterling formation through perforations below 2261'. Should you have any questions regarding this proposal, please contact Thomas R. Brooks at 564-6316. Sincerely, Doyle (. Oonef mrh ES5:50 cc: T. R. Brooks J. A. Dygas Bob Richey RECEIVED MAY- 7 1987 Alaska 011 & Gas Cons. Commission Anchorage UNITED STATES DEPARTMENT OF THE iNTERIOR GEOLOG I'CAL SURVEY 800 '~A' Street, Suite 109 ]h~chorage, Alaska 99501 D~rathon Oil Co~vpaz~r P.O. Box 2380 Anchorage, Alaska 99510 Attn: C.F. Ferguson IN REPLY REFER TO: .~Jarch 3, 1977 Gentlemen: In answer to yo~request for approval to conduct msoc~ronal gas tes~ ng on wells #1-A,~2~3, & 7 at the Beaver Creek Unit, we have no objections provided you c~ply with-notice to lessees #4, "Royalty Pa~m~ent on Oil & Gas Lost", and 30 CFR 221.44 '~asurement of Gas", and that the drawdown test not exceed 15 hours for egcn well. ~e ask that you keep the flaring to the =.~intmmn necessary to achieve test results by shortening the drawdown test periods to the minimum, and by e~.i:mLuating drawdown tests which are not necessary. We also ask that you contact this office 24 hours prior to sm~y testing so that we ~aylmve a representative there to ?~tness testing operations, and to furnish test results to this office upon completion of the testing. If you have ~¥ questions concerning the above requirements please feel free to call. Sincerely yours, (OR!G, SGD.) R. A: SMITH Hodney A. Smith 0fl & Gas Supervisor Alaska Area cc~---Division of Oil & Gas Conservation, State of Alaska STATE OF ALASKA ALAS~'~OIL AND GAS CONSERVATION COMI~/~..'$1ON APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon [] Suspend [] Operation Shutdown [] Re-enter suspended well [] Alter casing [] Time extension [] Change approved program [] Plugging [] Stimulate [] Pull tubing [] Amend order [] Perforate ~ Other [] 2. Name of Operator Marathon Oil Company 3. Address P.O. Box 102380 Anchorage, AK 99510 4. Location of well at surface 590' FNL, 1,979' FEL, Sec. 3 6N-10W-SM 5. Datum elevation (DF or KB) 155' KB 6. Unit or Property name Beaver Creek Unit 7. Well number BC-2 feet At top of productive interval Straight Hole At effective depth Straight Hole At total depth Straight Hole 8. Permit number 67-26 9. APl number 50-- 13320021-01 10. Pool Sterling 11. Present well condition summary -Total depth: measured true vertical 15,697' 15,697' feet Plugs (measured) 8,400' - 8,715' feet 5,221' (cmt & BP)il,740' - 11,950' (cmt) (cmt & BP) Effective depth: measured 5,221' true vertical 5,221 ' Casing Length Structural Conductor 280' Surface 2,211 ' Intermediate Production 8,835 ' Liner 10,159' Perforation depth: measur6~82' 5,258' (BP) 14,465' - feet 5,266; (BP) 14,915' feet 5,600' (BP) 15,407 ' 15,652' - Size Cemented Measured depth 20" 525 sx 280' 13 3/8" 2,000 sx 2,211' 9 5/8" 1,370 sx 8,835' 7" 650 sx 15,439' 5" 41 sx 15,697' B-3 5,155' - 5,220' true vertical B-3 5,155' - 5,220' Tubing (size, grade and measured depth) 3 1/2" N-80 @ 4,961' Packers and SSSV (type and measured depth) Baker FH Packer @ 4,923' 14,680' (cmt & pkr) ].5 7__' (cmt) 69 True Vertical aepth , 280' 2,211' 8,835' 15,439' 15,697' !986 Alaska 0it & Gas Cons. uo, p, mJssicn Anchora~je 12.Attachments< ~1 Description summary of proposal [] Detailed operations program [] BOP sketch [] 13. Estimated date for commencing operation November 1, 1986 14. If proposal was verbally approved Name of approver Date approved 15. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ~/~ ~'-- Title District Operations Engineer Date I ~/Zo/8~ Commission Use Only Conditions of approval Notify commission so representative may witness I Approval No. [] Plug integrity [] BOP Test [] Location cle~anceI Approvecl o~y .... ~~__~ Approved by ~/,[ ~~~~/~ Commissioner the commission Date FOrm Jq.:403.Rev 12q-85 ~ ~ / - 7 ' ' Submit~ triplicate Attachment #1 Beaver Creek 2 - Testing Procedure Hook up test separator (borrowed from Kenai Gas Field, if possible) and water storage tank. 2. Production test the B-3 sand (inject methanol down BV CL). · After testing the well for several days (minimum), conduct a 4 point isochronal test and PBU on slickline with GRC gauges downhole and at surface. Modify pressure testing per Reservoir Engineering's request. · Pending evaluation of well test data, a coil tubing squeeze or sand plug across the B-3 Sand will be considered~if needed. · Perforate the B-2 sand with 2 5/8" hollow carriers, 8 SPF, 5,125'- 5,140' DIL. 0 Test the B-2 (or the B-2 and B-3) sands for 1 week (minimum). Unload the tubing with N2 and coil tubing if necessary. 7. Conduct pressure testing per Reservoir Engineering's request. Se Rig down & release equipment. A decision will then be made whether to install permanent production facilities. PMO/lb/AFE286/35 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COiv~MISSION SUNDRY NOTICES AND REPORTS ON WELLS OTHER [] /'T~ 1. DRILLING WELL [] COMPLETED W E L L.~ 2. Name of Operator 7. Permit No. Marathon Oil Company 67-26 3. Address 8. APINumber P.O. Box 102380, Anchorage AK 99510 50- 133-20021 4. LocationofWell Surface: 590' FNL, 1979' FEL Sec. 3-6N-lOW-SM 9. Unit or Lease Name Beaver Creek Unit 10. Well Number BC #2 11. Field and Pool 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. _ 159' KB A-028118 Beaver Creek Field 12. Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF' (Submit in Duplicate) [] Altering Casing [] Abandonment [] Other (Submit in Triplicate) Perforate [] Alter Casing [] Perforations Stimulate [] Abandon [] Stimulation Repair Well [] Change Plans [] Repairs Made Pull Tubing [] Other [] Pulling Tubing (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). Open flow potential tests were not conducted because of the onset of cold weather. The original four point test was completed in May, 1974. Marathon intends, to resume testing in the summer of 1983. 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. ¥'(L--t--¢~ Title / The space below for Commission use Conditions of Approval, if any: By Order of Approved by. COMMISSIONER the Commission Date Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate "l.. February 16, 1983 Marathon Oil Company P.O. Box 102380 -Anchorage, Alaska.~99510 Res Subsequent ~eports, Sundry ~otices and Reports on Wells (Form 10-403 ) For the following lists of 'Notice of Intention To:" Sundry Notices and Report on ~ells (form 10-403) this office does not have on record the ~eSubsequent Report ofs~ defining the action taken on the. approved intention. of lice by Subsequ Beaver Cre ok 6 Beaver Creek 3 Beaver Creek 2' 'Beaver Creek 6 Beaver Creek 6 Beaver Creek 6 Please advise this ~nt_ Report of the.disposition, of the intention. . ~i, ara~h0.n Date .~r...t.e..f .D.e. scripti0n of._ .I.~tention 9/8/82 9/8/82 9/8/82 5/24/82 Open flow potential test Open flow potential test Open flow potential test Revised depth Completion and testing program Perforate and reperforate LC. S I KT l g lh C STATE OF ALASKA -~'~ ALASK IL AND GAS CONSERVATION C-.~VlMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL ~ · 2. Name of Operator 7. Permit No. Marathon Oil Company 67-26 3. Address 8. APl Number P.O. BOx 2380, Anchorage, AK 99510 50-133-20021 OTHER [] 4. Location of Well Surface: 590'S, 1979'W from NE corner Sec. 3-6N-10W-SM 5. Elevation in feet (indicate KB, DF, etc.) 140' GL 6. Lease Designation and Serial No. A-028118 9. Unit or Lease Name Beaver Creek Unit 10. Well Number BC #2 11. Field and Pool Beaver Creek Field 12. Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations E~ Altering Casing [] Stimulate [] Abandon [] Stimulation [] Abandonment [] Repair Well [] Ch'ange Plans [] Repairs Made [~' Other [] Pull Tubing [] Other [] Pulling Tubing [~ (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). Workover operations began September 27, 1982, and were concluded October 14, 1982. See Attachment for a record of operations. RECEIVED OCT 2 ? ]982 Alaska Oil & Gas Cons. Commission Anchorage 14. I hereby certify that ti~e foregoing is true and correct to the best of my knowledge. The space below for Commission use Conditions of Approval, if any: Approved by By Order of COMMISSIONER the CommissIon Date Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate ATTACHMENT BC ~2 Workover was completed as follows: 1. The well was killed w/ WO fluid and the 3-1/2" tbg was pulled and layed down. 2. The well was flow tstd from Sterling B-3 and B-3A at 4.74 MMCFD, 250 BWPD through DP. 3. The 7" lnr was cut at 5280' DPM, pulled and layed down. The 7" lnr stub was tagged at 5268' DIL. 4. A perm BP was set at 5262' WLM in the 9-5/8" csg. The well was perfd from 5259'-5261' WLM w/ 8 holes. Set rtnr at 5254' WLM & tstd. No flow. 5. A BP was set at 5233' DPM and a pkr was set at 5132' DPM to isolate B-3 perfs. The interval was flow tstd 5 hours at 6.06 MMCFD, 240 BWPD. 6. A cmt rtnr was set at 5233' DPM and 120 sx of cmt were sqzd into B-3A perfs at 5230 '-5244' DIL. 7. A retrievable pkr was set at 4950' DPM. The well was flow tstd 4 hours at 7.37 MMCFD, 307 BWPD. 8. A static temp log was run. The well was flow tstd again at 6.58 MMCFD, 201 BWPD, and a dynamic temp and noise log were run. Water entry was found in the Sterling B-3. 9. The pkr was reset at 5131' DPM for more tstg. The well was tstd for 8.25 hours at 6.98 MMCFD, 120 BWPD. 10. The 3-1/2" tbg was run and the Hyd pkr set at 4923'. The BPV was set and the well was SI. Total gas flared - 6919 MCF. RECEIVED OCT 2 ? 1982 Alaska 0il & Sas Cons, Commission Anchorage /'~ ST ATE OF ALASKA ?"'~ ALASKA oIL AND GAS CONSERVATION CC,~MISSION SUNDRY NOTICES AND REPORTS ON WELLS OTHER DRILLING WELL [] COMPLETED WELL IXI 7. Permit No. 2. Name of Operator Marathon Oil Company 67-26 3. Address 8. APl Number P. O. Box 2380, Anchorage AK 99510 50-133-20021 4. Location of Well Surface: 590'FNL, 1979'FEL, Sec 3-6N-10W-SM 5. Elevation in feet (indicate KB, DF, etc.) _ 158.5' KB 6. Lease Designation and Serial No. A-028118 9. Unit or Lease Name Beaver Creek Unit 10. Well Number BC #2 11. Field and Pool Beaver Creek Field 12. (Submit in Triplicate) Perforate [] Alter Casing [] Perforations Stimulate [] Abandon [] Stimulation Repair Well [] Change Plans [] Repairs Made Pull Tubing [] Other ~ Pulling Tubing (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Duplicate) [] Altering Casing [] Abandonment [] Other 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). It is Marathon's intention to conduct an open flow potential test on Well #2 upon completion of well workovers in the field. The testing should be completed by the end of October, 1982. 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. The space below for Commission use ~l Date Conditions of Approval, if any: FORM 10-421 (GAS WELL OPEN FLOW POTENTIAL TEST REPORT) to be submitted in duplicate within 30 days after completion of tests. Approved Copy ORIGINAL SIGNED Returned By Order of ,,~--/¢- d6,'~'- /,~_ //~ ~-0¢ ~ : Approved by BY [0NNIE i~. SMITH COMMISSIONER the Commissiqq_.,. . , D,a.te__' Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate 1'" STATE OF ALASKA ~_. ALASKA(~ .'L AND GAS CONSERVATION C" ~MISSION SUNDRY NOTICES AND REPORTS ON WELLS DRILLING WELL I-I COMPLETED WELLX~ ' OTHER ,[] 7, Permit No. 7 1. 2. 'Name of Operator Marathon Oil Company 67-26 3. Add~ess 8. APl Number P. O. BOX 2380, Anchorage AK 99510 50-133-20021 9. Uhit or Lease Name Beaver Creek Unit 4. Location of Well Surface: 590' S, 1979' W from NE corner Sec 3-6N-10W-SM 5. Elevation in feet (indicate KB, DF, etc.) 155' KB I 6. Lease Designation and Serial No. A-028118 10. Well Number BC #2 11. Field and Pool Beaver Creek Field 12. Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate ~[ Alter Casing _ F-I ~ Perforations [~] Altering Casing [] Stimulate [] Abandon [] Stimulation [] Abandonment [] Repair Well ~ Change Plans [] Repairs Made [] Other [] Pull Tubing ~ Other ' [] Pulling Tubing FI (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting an~ proposed work, for Abandonment see 20 AAC 25.105-170). Proposed operations for August 1982 include pulling and inspecting tubing, installing a methonal injection system, and reperforating Sterling Bench 3 and Bench 3A as follows: Bench 3 5155' - 5220'-DtL, 2 HPF Bench 3A 5230' - 5244' DIL, 2 HPF EC iVED SubsequevA Wm:k ~.eportecl ,~'onzz ,[No - · J U L - 9 i982 Alaska 0il & Gas Cons. Commission Anchorage 14. I here~3y certify that~J~e foregoing is true and correct to the best of my knowledge. Signed [~,) __ _ Title 0--erati°nsp Engineer The space below for Commission use Date July 6, 1982 Conditions of Approval, if any: Approved bY Approved Copy Returned By Order of COMMISSIONER the Commission Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate BEAVER CREEK FIELD GAS WELL TEST PROCEDURE Run the bottom hole pressure bomb/to the well. Open the well for 15 hours drawdown test at a stabilized rate of 20~0 MCF per day. ~.- Shut the well in for 15 hours buildup. 4. Run modified isochronal test at daily rate of 2000 MCF, 5000 MCF, 8000 MCF and 10,000 MCF at a At of 1 hour. . ~u~e recorder is also needed during the above test. 6. Pull the pressure bomb at the end of the test. AtD= AtB = 15 hrs Atl = At2 = At3 = At4 = At5 = At6 = 1 hr. At7 = tpss : 2 hrs. if A = 640 acres ]( = 2 darcys · o'! Anch¢ Division Produc, .n Operations US & Canada Marathon Oil Company PO Box 2380 Anchorage Alaska 99510 Telephone 907/274 1511 February 17, 1977 Mr. Rodney A. Smith Regional Director United states Geological Survey P. O. Box 259 AnChorage, Alaska 99504 Dear Mr. Smith: BEAVER CREEK UNIT WELLS 1-A¥2~3 & 7 STERLING GAS SAND - ISOCHRONNk[~.TESTING The purpose of this letter is to solicit your approval for flaring of gas during testing of the Sterling gas ~and in several wells at Bea¥~r Creek. Marathon Oil Company proposes to run modified isochronal tests on each of the above referenced wells during the month of March, 1977. Each well will be tested for a period of several days to maximum rates of about 10 MMSCFPD through a portable separator and flare stack. An outline of the proposed tests is attached. Yours very truly, C. F,--Ferguson J~' Division Petroleum Engineer CFF: kbs cc: H. H. Hamilton Division of Oil and Gas Conservation R. A. Richey U. S. Dept. of Fish and. Wildlife RECEIVED FEB 1819'/7 D~ el O# & OJ~: ~lt~ MARATHON OIL COMPANY pI~-ODUCTION-UNITED STATES AND CANADA ANCHORAGE DIVISION June 19, 1974 Mr. W. C. Wunnicke U. S. Geolo§ical Survey P.O. Box 259 Anchorage, Alaska 99510 P.O. BOX 2.mSO ANCHORAGE , ALA Ic. I , --i 'r-! ~f~a'"iKI ---i'- ~ ~.~o~ I ~E.~:I I~FTt -- I SEC I CONFER: ~tLE: Dear Mr. Wunnicke: Attached please find two ~mpletion Notices, Form 9-330, for Beaver Creek Unit Wel~#2~ One notice shows the results of the "G" Zone tests, whl~3~r~failed to recover hydro- carbons. This notice details the subsequent plugging and abandonment of the "G" Zone. A brief suma~ary of the entire operation, i.e. clean-out, cement squeeze, perforations, and stimulation, is attached to 'provide clarity. The second completion notice outlines the work related to recompleting BCU Well #2 in the Beaver Creek Gas Sands. This recompletion in the gas sands was accomplished by per- forating the recently-run 7" tie-back liner and 9-5/8" casing behind from 5,155' to 5,220' and 5,230' to 5,244'. These intervals provided a combined test rate of 3.0 MMCFPD, which was the limit of the separator on location. A back pressUre valve was' set and BCU Well #2 remains shut-in at this time as we have no gathering lines to the well. We have submitted two separate completion forms for this operation in an attempt to fully describe (1) "G" ZOne testing and abandonment, and (2) recompletion and testing of the gas sands. Marathon hopes this will satisfy your requirements, but should you have further questions, please feel free to contact us. Yours very truly, H. D. Lee HDL/pr Attachments cc: Mr. H. H. Hamilton'~ Division of Oil .& Gas State of Alaska 3001 Porcupine Drive Anchorage, Alaska 99504 (w/attachments) -63) / / . ED STATES sUBmT IN Dm'r, E* ( S',,,., , :',er I n- DEPARTMENT OF' THE 1NTrRIOR ~' reverse side) GEOLOGICAL SURVEY WELL COMPLETION OR RECOMPLETION REPORT AND LOG* la. TYPE OF WELL: (iii, [---] WELL b. TYPE OF COMPLETION: NEW [~ WE,,,, ,,,-m, CAS ~ BaY ~ Other w E L L PI,DGF-] DIFF. [-~ BACK RESVR. Other 2. NAME OF OPERATOR Marathon Oil Company 3. Al)DRESS OF OPERATOR P.O. Box 2380, Anchorage, Alaska 99510 4. I,OCATION OF WEI,L (Report location clearly and in accordance with any State requirements)* At surface 590! FNL & 1,979~ FEL of Sec. 3, T6N, R10W, S.S. At top prod. interval reported below Straight hole At total depth Straigt hole [ I4..ER~,IT NO. DATE i~suED State 67-26 [ 6/9/67 Form approved. Budget Bureau No. 42-R355.5. 5. LEASE DESIGNATION AND BERIAI, NO. USL-A-028118 6. IF INDIAN, ALLOTTEE OR TRIBE NAME Beaver Creek Unit lq. FARM OR LEASE NAMe] Beaver ,Creek : 9. WELL NO. · '- 2 10.'fIELD A~D POOL, OR WILDCAT Beaver Creek, "G" Zone Il. SEC., T., R, M., OR BLOCK AND SURVEY OR AREA Sec. 3, T6N, R10W, S.M. 12. COUNTY OR [ 13. STATE PARISH Kenai Borougt~ Alaska 15. DATE SPUDDED 16. DATE T.D. REACHED 17. DATE COMPL. (Ready to prod.) [ 18. ELEVATIONS (DF, RKB, RT, OR, ETC.)* 19. ELEV. CASINOIIEAD 7/13/67 11/9/67 Orig. - 12/26/67 ] Grd. Level = 140.3' 141.4' ' ~'~i[¥~¢-~-~o---[-15,697 MD & . 5,600 I , I 21. PLUO, BACK T.D.. MD & TVD 22. IF MUI,TIPI,E COMPL., 23. INTERVALS ROTARY TOOLS CABLE TOOLS ' TVD ' . HOW MANY* DRILl, ED BY I -- > All -- 24. PRODUCING INTERVAL(S). OF THIS COMPLETION--TOP, BOTTOM, NAME (MD AND TVD)* '. 25. was DIRECTIONAL '. suav~ ~ADE "G" Zone--14,700' - 14,730', 14,760' - 14,839', & 14,841' - 14,866' '. Yes (These intervals tested dry & have been P.& A--see attachment) 26. TYPE ELECTRIC AND OTHER LOGS RUN 27.WAS WELL CORED On Init. Compl.--IES, DIL, Sonic, Density, GR, Dipmeter, & CBL No 22. CASING RECORD (Report al~ strings set in welt) ttOLE SIZE - CEMENTING RECORD AMOUNT PULLED: _~^ sj N O~ SLZE_ 7" tie-back W,,,,,',T. LB./~T:. j liner du. rin1_ DEPTH SET (MD) / WO--see att chment 29. LINER RECORD SIZE TOP (MD) BOTTOM (MD) 7" OD 4,974' 8,615' -- SACKS CEMENT* 170 sack~ SCREEN (MD) 30. TUBING RECORD SIZE DEPTH SET (MD) PACKER SET (MO) 31. PERFORATION RECORD (Interval,-size and, number) See attached record 32. ACID. SHOT, FRACTURE, CEMENT SQUEEZE. ETC. DEPTH INTERVAL (MD) / AMOUNT AND KIND OF MATERIAL USED See attachel record 33.* PRODUCTION DATE FIRST PRODUCTION PRODUCTION METHOD (Flowing, gas lilt, pumping--size and type o! pump) j WELL STATUS (Producing or 4/22/74 Gas lift J shut-i.) SI DATE OF TEST5/20/74 ' .OURS TESTZD__ CHO~E SIZE0pen TEsTPROD'N' FORpERIOD__ j OII~---BBL.Dry j ¢.AS--MCF.Dry . WiTER BBL. , J GAS'OIL RATIODry ' ---- 34. DIEPOSITION OF OAS (Sold, used for fuel, vented, etc.) J TEST WITNESSED BY "G" Zone was plugged h abandoned as non-productive ~ W.T. ~ite 35. LIST OF ATTACHMENTS _~_)_ Detailed summary_of operations, and (2) Gyro directional survey 36. I hereby certify th~l~ched information is complete and correct as determined from all available records SIGNED //~~,~_ TITLE Act. OpeN. Sup ' t. DATE ,, 6./19/74 'H' P. Lo-e- *(See Instructions and Spaces for Additional Data on Reverse Side) Pc~m 9-330 (Rev. 5~63) ED STATES SUBmT IN DUrL, ( See Olher iD- DEPARTMENT OF THE INTERIOR ,,,..,.ti,,.,,-,,, reverse side) GEOLOGICAL *U RVEY WELL COMPLETION OR RECOMPLEIION REPORT AND LOG* la. ',".'P,~ O," W~.I.: O,LIZl,;AS F'Xl EEl WELL W ELI, DRY Other b. TYPE OF COMPLETION: ""wP1 'v""I"lEl D~'":P'E] """"ID D'"F'F1 WEI,I, OVEI~ EN BACK RESVR. Other 2. NAME OF OPERATOR Harathon 0il Company 3. Al)DRESS OF OPERATOR P.O. Box 2380, Anchorage,' Alaska 99510 4. LOCATION OF WELL (Report location clsarly and in accordance with any Slate requirements)* At surface 590' FNL & 1,979' FEL of Sec. 3, T6N, R10W, S.M. At top prod. interval reported below Straight Hole At total depth Straight Hole 14. PERMIT NO. DATE ISSUED State 67-26 6/9/67 Form approved. Budget Bureau No. 42-R355.5. 5. LEASE I')ESItlNATION AND ~{CRIAI, NO. USL-A-028118 6. IF INDIAN, ALLOTTEE OR TRIBE NAME -i; ~ i'¢--/,~ii&. ~: d~;i' '-'/~ * ~i E Beaver Creek Unit ~q. FARM OR LEA~iE NAME Beaver Creek 9. WELL NO. 2- 10. FIELD AND POOL, OR WILDCAT Beaver Creek Sterling Gas .Sands 11. sEC., T., R., ~., OR BLOCK AND SURVEY OR AREA Sec, 3, T6N, RiOW, S.M. 12, COUNTY OR ! 13. STATE PARISH Kenai Borougl Alaska 15. DATE7/13/67SPUDDED 16. 11/9/67DATE T.D. REACHED t 17 PATE5/27/74COM PL. (Ready to prod.) 18.Grd.ELEVATIONSLevel(DF,=RKB,140.RT, ~R~ ETC.)* 19. 141,4 'ELEV' CASIN(] IIEAD --- > All -- 24. PRODUCING INTERVAL(S), OF THIS COMI'LETION- TOP, BOTTOM, NAME (MD AND TVD)* 25. WAS DIRECTIONAL SURVEY ~IADE Beaver Creek Gas Sands - 5,155' to 5,220' and 5,230' tO 5,244' No'. - 26. TYPE ELECTRIC AND OTHER LOGS RUN I27.WAS WELL CORED No I No 2,q. CASING RECORD (Report all strings set in well) CASING SIZE VVEIGHT, LB./FT. DEPTH SET (MD) HOLE SIZE CEMENTING RECORD AMOUNT PULLED None 29. LINER RECORD 30. TUBING RECORD TOP (MD) BOTTOM (MD) SCREEN (MD) DEPTH SET (MD) PACKER SET (MD) SIZE None ISACKS CEMENT* SIZE ~-1/2" OD 5,067' 5,059' 31, PERFORATION RECORD (Interval, size and number) 5,155' - 5,220' 0.28" 130 holes 5,230' - 5,244' 0.28" 28 holes 32. ACID, SHOT FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (1HD) AMOUNT AND KIND OF MATERIAL USED None 33.* PRODUCTION DATE FIRST PRODUCTION [ PRODUCTION METHOD (Flowing, gas lift, pumping--size and type of pump) WELL STATUS (Producing or 5/27/74 I Flowing ~hu~-tn) SI DATE OF TEST HOURS TESTED CIIOKE SIZE PROD'N. FOR OIl. r---BBL. GAS MCF. WATER BBL. 0AS-OIL RATIO 5 / 2 7 / 74 3 1 / 2" TEST rERIOD __ > 1 [ 375 .... 34. DISPOSITION OF OAS (~0ld, used for fuel, vented, etc.) TEST WITNESSED BY Vented during test--well now SI--no pipeline D.B. Hopkins 35.LIST OF ATTACHMENTS None 36.~ hereby certify that the foregoing and att~i'ed Information Is complete and correct as determined from all available records TITLE Act. Oper. Supt. 6/19/74 DATE *(See Instructions and SPaces tor Additional Data on Reverse Side) INSTRUCTIONS Gcncrah This form is designed for submitting a complete and correct well completion report anti log on all types of lands and leases to either a Federal agency or a State agency, or both, pursuant to applicable Federal and/or State la~vs and regulations. Any necessary special instructions concerning the use of this form and the number of copies to be submitted, particularly with regard to local, area, or regional procedures and practices, either are shown below or will be issued by, or may be obtained from, the local Federal and/or State office. See instructions on items 22 and 24, and 33, below regarding separate reports for separate completions. If not filed prior to the time this summary record is submitted, copies of all currently available logs (drillers, geologists, sample and core analysis, all types electric, etc.), forma- tion and pressure tests, and directional surveys, should be attached hereto, to the extent required by applicable Federal and/or State laws and regulations. Ali attachments should be listed on this form, see item 35. Item 4: If there are no applicable State requirements, locations on Federal or Indian land should be described in accordance with Federal requirements. Consult local State or Federal office for specific instructions. Item 18: Indicate which elevation is used as reference ' (where not otherwise sho~vn) for depth measurements given in other spaces on this form and in any attachments. Items 22 and 24: If this well is completed for separate production from more than one interval zone (multiple completion), so state in item 22, and in item 24 show the producing interval, or intervals, top(s), bottom(s) and name(s) (if any) for only the interval reported in item 33. Submit a separate report (page) on thia form, adequately identitied, for ea(.h additional interval to be separately produced, showing the additional data pertinent to such interval. Item 29: "Sacks Cement": Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 3]: Submit a separate completion report on this form for each interval to be separately produced. (See instruction for items 22 and 24 above.) 37. SUMMARY OF POROUS ZONES: . SHO'~,' ALI, IMPORTANT ZONES OF POROSITY AND CONTENTS THEREOF; CORED INTERVALS; AND ALL DRILL-STEM TESTS, INCLUDING 38. GEOLOGIC MARKERS DEPTH INTERVAL TESTED, CUSHION USED, TItlE TOOL OPEN, FLOWING AND SHUT-IN PRESSURES, AND RECOVERIES FORMATION TOP BOTTO~I DESCRIPTION, CONTENTS, ETC. TOP 'No DST's or c~ ,res taken. NAME MEAS. DEPTH TRU~ ¥1:RT. DI~PTH Beaver Creek Gas Sands 5,136' 5,136' U.S. GOVERNMENT PI~INTING OFFICE: 1963---O-683636 87 1 - 23 3 K. A. Thoma "'~' ~ 6/14/74 BEAVER CREEK UNIT WELL 2 Summary of Workover Operations to -Test "G" Zone 3/8-19/74 5/20-22/74 3/23-26/74 3/27-4/6/74 4/7-14/74 4/15-18/74 Initiated workover operations on BCU Well 2 at 12:01 AM, 3/8/74. Prior to workover, this well was shut-in with perforations in the 9-5/8" casing from 5,155'-5,220' and from 5,229'-5,244' in the Beaver Creek Gas Sands. The tubing and packer at 5,073' were pulled and the bridge plug at 5,267' was drilled out. The perforations from 5,324'-5,344' were cement squeezed as these were shot in error in 1967. A bridge plug at 5,624' was drilled out and the well cleaned out to top of the 7" liner at 8,609'. Ran a 7" tie-back liner to isolate gas sand perforations with following detail: Ran 84.jts. of 7" OD, 29#/ft., N-80, x-line casing and cemented with 170 sacks of cement. Top of screw-set liner packer with t%e-back sleeve .... ~ .............. 4,974' Top of 7" x 9-5/8" liner hanger ...... 4,983' Top of 7" x 9-5/8" Hyd. liner packer . . . 5,036' Top of 7" X 9-5/8" Hyd. liner packer (2nd). 5,296' Bottom of liner with 6' tie-back seal assembly ................. 8,615' The packers at 4,974', 5,036', and 5,296' were run to assure isolation of the gas sands. This seal was tested with.a DST and proved to be dry - no liner lap leaks. The well was cleaned out to 15,337', a bridge plug was set at 14,915', and a Gyro-directional survey was run to surface. Four perforations were shot from 14,902'-14,903' and squeezed with 190 sacks leaving PBTD at 14,880'. Four holes were shot from 14,660'-14,661' and cement squeezed with 640 sacks in four jobs. The squeezes at 14,902' and 14,660' were necessary to assure isolation. of the "G" Zone. A casing leak in the 7" liner was located at 12,295' and was cement squeezed with 180 sacks. The production tubing string was run with a permanent packer at 14,680' and a hydrostatic-retrievable packer 4/15-18/74 Cont ' d. 4/19-26/74 4/27-5/4/74 5/5-13/74 5/14-20/74 s/21-24/74 NOTE: at 11,900' to assure isolation of the casing leak at 12,295'. The "G" Zone was perforated with thru-tubing guns as follows: Inverval Ft. HPF Total Shots' ~ Hole Size 14,715'-725' 10' 2 20 ' 0.33" 14,780'-795' 15' 4 60 0.33" 14,844'-866' 22' 2 44 0.33" Total 47' 124 Holes Total recovery after two days of gas lifting was 10 BBLS of oil/water/gas emulsion. As there was no significant hydrocarbon recovery from the thru-tubing "G" Zone perfs, the tubing string was pulled and the permanent packer at 14,680' was milled over and recovered. The "G" Zone was then perforated using 4" Casing guns as follows: Interval Ft. HPF Total Shots · Hole Size 14,700'-730' 30' 4 120 0.40" 14,760'-790' 30' 4 120 0.40" 14,794'-839' 45' 4 180 0.40'" 14,841'-856' 15' 4 60 0.40" Total 120' 480 Holes The "G" Zone was then tested with DST tools, bUt no recovery. A 2,000 gal. acid stimulation through drill pipe was performed, but had no hydrocarbon recovery. The "G" Zone perfs were again stimulated through tubing with 10,000 gallons of acid. There was no recovery by flowing the well or by swabbing. While attempting to release the packer, the tubing parted at 491'. An overshot was used to recover all the tubing. The production tubing string was run j.ust that run on 4/15/74. There was no hydrocarbon recovery through three days of gas lifting and a 24-hour static BHP survey showed 2,078 psi at 14,600'. Plugging and abandonment of the BCU Well 2 "G" Zone was accomplished as follows: Blanking Plug in Tail Pipe (below perm. pkr.). . 14,691' Cement Plug ............. 14,480' to 14,680' Bridge Plug ................... 13,950' Cement Plug ............. 11,750' to 11,950' Cement Plug ............. 8,400' to 8,715' Bridge Plug ................. 5,600' ll.0#/gallon mud was left in the hole ~'etween plugs. See accompanying Completion Notice (Form 9-330) for de- tails of recompleting BCU Well 2 in the Beaver Creek Gas Sands. 5/19-20 Cont'd. survey with maximum recorded pressure of 2,078 psi at 14,600' after 24 hrs. SI. 5/21-22 Began operations to plug & abandon the "G" Zone. Set a blanking plug at 14,691' in the tailpipe below the permanent packer at 14,680'. Loaded the hole with mud, set back pressure valve, removed X-mas tree, and installed BOPE. 5/23-24 Pulled production tubing string. Set cement plugs from 14,480' to 14,680', from 11,750' to 11,950', and from 8,400' to 8,715'. In addition bridge plugs were set at 11,950' and 5,600'. Left ll.0#/gal, mud in well between all plugs. 5/25 Displaced mud from hole with diesel above BP at 5~600'. Ran 3-1/2" produc- tion tubing string to 5,067' with packer at 5,058'. Set back-pressure valve, removed BOPE and installed X-mas tree--tested to 5,000 psi - O.K. 5/26-27 Perforated Beaver Creek Gas Sands thru-tubing with 2 HPF from 5,155' to 5,220' (65') and from 5,230' to 5,244' (14'). Unloaded well through separator and tested at 3 MMCFPD with 1,850 psi FTP (capacity of separator). Ran BH.P survey, indicating 2,205 psi at 5,200' . Installed back-pressure valve and shutin well. UNITED STATES ' DEPARTMENT OF THE INTERIOR GEOLOGICAL SURVEY Approval oxplrel 12-31-55. AND OFFICE ................................... LEASE NUMBER ................................. UNIT ............................................ LESSEE'S MONTHLY REPORT OF OPERATIONS State ........ .A..1.~.q_k..a. .............. County .................................... Field ....... B_._e_~v__.e.r.__..C.r__.e.~.k. ................................... The followin~ is a correct report of operations a~d .prod~otior~ (ineludO~ drillin~ az~d prod~ein~ wells) for the month o£ ....... : ....... ~_a_y_ ...................... , 19_.7._~, /l~e~t's address ____P__:___O__:___B_P~____2_3___80__A__n__c_..h__o_~_,___~...__9_??__j:~ ...................................... - . "C°mpa~Y Marathon Oil Co._mj2_a~ Phon, e _._: ............... 2~/4~--]:5-L1 ................................................... ,~eT~t' s tltle.Ac, k±ng_.Opar, a tfaf:1~__$up_t_ .......... ~EC. AND' ~ Or ~ T ,r. B'EAVE , ,, Repor e } Zone e t was r c )m .5/1-4 ~/~-6 ~/7-1 5/~- 5 5/16-Is ~/19-[0 (See ~tta~ RANGE WEI.L NO. .__ ',El(. I ~IT: ,elo~ ar~ ', rec )vel .lete J ir Mi] led per ~ore " tO S WELL the ed no 'the ] ~ver ~ ted "( 14 14 14. ]~JARREL$ OF OIL .#~, ~EC~O~ ~ctivities ! oil, the ' eaver Cre( recoverec Zone usJ 700'-14,7: 760'-14,7~ 794'-14,8: 14i841'-14,8~ Total &,DST valve Ran BHP s~ CU FT OF O'" GALLONS OF ]BARRELS Og RIgMARKS GRAVITY / .'. ' .. '~zt2] OASOLINE ~VATER (If (If drilling, depth: If shut down, ca~e; ~ln ~nousan.s) ~COV~a~" none, sO stato> da~, and r;g~:n ~hSch occurred ~n ~ay, ':97~, during which the "¢". G" Zoae was plu~;ged and abandone0, and thSs well k Gas Sands.i . ~ k ::p 1~,680''~ . Re- .perm:~nenr prod, tct~on p~c er f ~ ~ , casz g gulls, 4 HP~ as fo ows: JUNt81974 ' ' 0! 30 ft. - 20 holes 30 .ft. - 20 hole~ 45 ft. - ~80 holes 115 ft. - 60 boles ~ ft 80 holes with.~,000' of diesel cu .rvey ~ith 1,646 psi at l '! ' ;" Zone perforations with 2,000 gal ,600 psi ~ no o~1 recover~. "Zone perforations with i0,000 ga ,000 psi ~ no o~1 recover~. Swabb LOedt 3a:dl/~'j~otvUeb en~ aa~14~ul~i~ghialnedt;Ya ',repletion lubi gl string wiIh perman ,acker at ~1,9 07. Remove4 BOPE an : frOm hol~ wi h/water; th~;n displa el with g~s 1 f~' system, ,ut reco~ ~aximum re]ord dlpressure ,f 2,078 shion. 4,650#. ions of llons of ed well ing to r cker. ent pack, d instal~ ced wate~ ered no 3si at 1 rIsi N 01L gAS {ad no recovery ~cid at maximum acid at maximum ¢ith no oil re- ~lease packer. ~r at 14,680' and _ed X-mas tree. with diesel. il. Ran BHP ,600' after Now~.--There were ...................................... runs or sales of oil; .............................................. M cu. ft. of gas sold; .............................................. runs or sale. s of gasoline during the month. (Write "no" where applicable.) No~'z.~Report on this form. is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the supervisor by the 6th of the succeeding month, unless otherwise directed by 'the supervisor. Form 9-329 16~257§6"~ U, S. GOVERNMENT PRINTING Or~lCl (January 19~) 5/21-22 5/23-24 5/25 5/26-27 Began operations to plug & abandon the "G" Zone. Set a blanking plug at 14,691' in the tail pipe below the permanent packer at 14,680t. Lo'aded the hole with mud, set back pressure valve, removed X-mas tree, and installed BOPE. Pulled production tUbing string. Set cement plugs from 14,480' to 14,680~ from 11,750' to 11,950', and from.8,400' to 8,715'_ In addition bridge plugs were set at 11,950' and 5,600'. Left ll.O#/gal, mud in well between all plugs. Displaced mud from hole with diesel above BP at 5,600'. Ran 3-1/2" produc- tion tubing string to 5,067' with packer at 5,058'. Set back-pressure valve, removed BOPE and installed X-mas tree--tested to 5,000 psi - O.K. Perforated Beaver Creek Gas Sands thyu-tubing with 2 H?F from 5,155' to 5,220' (65') and from 5,230' to 5,244' (14'). Unloaded well through separator and tested at 3 MMCFPD with 1,850 psi FTP (capacity of separator). Ran BHP.survey, indicating 2,205 psi at 5,200'. Installed back-pressure valve and shutin well. JUN '1_ 8 'i974 DX¥1SI JN OF OIL AND C AS WELL STATE OF AI.A~KA SVsMrr IN DU~'LZCA~ OIL AND GAS CONSERVATION COMMITTEE MONTHLY REPORT O'F :DRILLING AND WOR'KOVER OPERATIONS 2. NA/~E OF OPEtR~TOR Marathon Oil Company 3. ADbRESS OF OPEI~ATOR P. 0. Box 2380, Anchorage, AK 99510 4. LOCATION OF WELL Surface: 590' FNL, 1979' FEL, Sec. 3, T6N, R10W, SM iP, N~s~C~L CODE [' ~ "E'~ 50-133-20021 .... I L~SE DESIGNA~ON AND S~IAL N~. A-028118 ~z~ ~.~ o~ LE.ss Beaver,, Creek UnzC l; ~'~ I 2 q~a~E'Ri: 10. FI[~.n ~ND P~L, OR WILDCAT Bevaer Creek Gas Sands- 11. SEC., T., R., M., (BOTTOM HOL~ (Straight Hole) 1~.. PERMIT NO. 67-26 13. REPORT TOTAL DEPTH AT END OF MONTH, CI-L~NGES IN HOLE SIZE, CASING AND CEMENTING JOBS INCLUDING DEPTH SET A1W%) VOLLrBT~ USED, PERFORATIONS, TESTS AND RESULTS, FISHING JOB~, jLrNK IN HOLE AND SIDE-TR~CKED HOLE ANT) ANY OTHER SIGNIFICA/~T CI-IAN-~ES IN HOL~ CONI)ITIONS. BEAVER CREEK UNIT, WELL #2, RECO~LETION- MAY, 197.~. Reported below are the activities which occurred in May, 1974, during which the "G" Zone tests recovered no oil, the "G" Zone was plugged and abandoned, and this well was re- completed in the Beaver Creek Gas Sands. 5/1-4 5/5-6 14,700'-14,730' 14,760'-14,790' 14,794'-14,839' 14,841'-14,856' Total 30 ft. - 120 holes 30 ft. - 120 holes 45 ft. - 180 holes 15 ft. - 60 holes 120 ft. 480 holes Milled over & recovered permanent production packer from 14,680'. Reperforated "G" Zone using 4" casing guns, 4 HPF as follows: JUN i 4 DIVISION OF OIL AND GAS ANCHORAGE Ran packer & DST valve with 2,000" of diesel cushion. Had no recovery to sur-. face. Ran BHP survey with 1,646 psi at 14,650#. 5/7-11 Stimulated "G,' Zone perforations with 2,000 gallons of acid at maximum pressure of 5,600 psi - no oil recovery. 5/12-15 Stimulated "G" Zone perforations with 10,000 gallons of acid at maximum pressure of 6,000 psi - no oil recovery. SWabbed well with no oil recovery. Parted 3-1/2" tubing at 491' while trying to release packer. Ran an overshot and recovered all tubing and packer. 5/16-18 Ran 3-1/2" completion tubing string with permanent packer at 14,680' and re- trievable packer at 11,900'. Removed BOPE and installed X-mas tree. 5/19-20 Displaced mud from hole with water; then displaced water with diesel. Unloaded diesel with gas lift system, but recovered no oil. Ran BHP (See attached .sheet) 14. 1 hereby certify %1~ ~,]~for o~ ~rue and correct Acting /~~~' ~ Operations SuperintendeB~' June 13 ~ 1974 SIG~ ~ ~. -~. mee · NOTE--Report oa %~is form is required for each ~l~r mga%h, regardless of the staLus of operations, and must ~ file~ i~ duplica%~ with %he Division of ~iaes & ~iaerals by the 15%h of %~e succeeding month, unless othe~ise directed. Form I0-405 ~bmit "Intentions" in ~-tplimt~ ~V. ' I - ~0-~ . ~ "Su~qaent ~s" ~ Dupli~te STATE .... , Ol~ AND GAS ...... CONSERVATION ~O~l~E~ 50-133-20021 SUNNY NOTICES AND R~ORTS ~ W~ A-028118 (~ not use this fo~ for proposals use -~.~CA~ON *~O~ 01L WgLL Marathon Oii Company , , Beaver Creek Uni~ P. O. Box 2380~ Anchora~e~ . at~ Beaver Creek - 590' ~L, 1979' FEL, Sec 3, T6N, R10W, SM n's~c*,w',~',~.,(s~~o~ . O~M~IV~) ($ traight hole) 1~. ELEVATIONS (S~ow whether DF. ~T. GR. etc. 12. ~T ~O. 158.5' KB, 140.3' Grd (Ail Measurements from KB) 67-26 Check Appropriate Box To tndicate N~ture 'of I~tice, Report, or Other Dat~ ' NOTICE OF INTENTION TO: FRACTURE TREAT MULTIPL~ COMPI,ETI~ REPAIR WELL CHANG~ PLANe -- WA,.R .aUT-Or, I ~[" I R,~AIRZ~G WE',L ~ tOther) / (NOTE: Report results of multiple completion on Well - , , Com~,letion or Recompletion Report and LoS form.) 15 DEI~CRIBE PROPOSED OR COMPLETED OPERATIO.%'a (Clearly state all pertinent details, and gh-e pertinent dates, including estimated date of starting any proposed work. The workover of Beaver Creek Well 2 failed to recover oil from the ,,G,, Zone. The following is a report of plugging and abandoning the "G" Zone and reCompleting Well 2 in the Beaver Creek Gas Sands: 5/21-24 Set blanking plug in "Q" Nipple @ 14,691', below permanent'packer @ 14,680'. Spotted cement plug from 14,480' to-14,680'. Set bridge plug @ 11,950' with ll.0#/Gal, mud from 11,950' to 14,480'. Spotted cement p~ugs from 11,750' to 11,945' and from 8,400' to 8,715' (tie-back liner lap @ 8,615'). Set bridge plug @ 5,600'. 5/25 Displaced mud from hole with diesel above BP @ 5,600'. Ran 3-1/2" produc- tion tubing string to 5,067' with packer @ 5.,058'. Set back-pressure valve, removed BOPE and installed X-mas tree-tested to 5,000 psi - O.K. 5/26-27 Perforated Beaver Creek Gas Sands thru-tubing with 2 HPF from 5,155' to 5,220' (65') and from 5,230' to 5,244' (14')'. Unloaded well through separator and tested @ 3 MMCFPD with 1,850 psi .FTP (capacity of separator). ' _ ..... ~a~-,~HP survey, indicating 2,205 psi at 5,200'. Installed back-pr, essure ~ ~ ~ U ..~ ~a~ and shutin well. -' . ~[~[~0~ ~~ ~~-"-' '-~,ZT~, Operation Superintendent June 4, 1974 ~ ~D ~ ~D~v 1'~.. ,Tmn~M ..... DATE APPROVED BT CONDITIONS OF APPROTAL, IF ANT: TITLE DATE See I, nstrucfions On Reverse Side ppmved Capy . Returned . II ii , i--- - ._ ~ Form I0 -403 ~.EV. I - i0-7~ STATE OF ALASKA Submit "Intentions" in Triplicate & "Sub,sequent Reports" in Duplicate OIL AND GAS CONSERVATION COMMITTEE SUNDRY NOTICES AND REPORTS ON WELLS ldo p, ot use this form for proposals to drill or tO deepen ~J~ Ak,IFIMCATION 'FOR ~'ERI~I'F-L" '~or such'proposals*.) 2. NAME OF OPERATOR Marathon 0il Company 3 ADDRESS OF OPEI:~ATOR P. 0. Box 2380, Anchorage, Alaska 99510 4. LOCA'II£)N OF WELL Atsurface 590' S, 1979' W, NE Corner, T6N, R10W SM 5. APl NUMERICAL CODE '6. I-,E~sE DESIGNATION A. ND SERIAL NO. A-028118 7. IF INDIAIq. A,L~,O'I'I'EE OR TRIBE NAJVLE 8. UNIT, FARNI OR LEASE NAME Beaver Creek Unit 9. %ATOLL NO. 2 10. FIELD AND POOL, Oil WILDCAT Beaver Creek - G Zone 11. SEC., T., R., M., (BOTTOM HOL~ OBJECTIVE) - Straight Hole 13. ELEVA'F1ONS (Show whether DF, RT, OR, etc. 12. PEltMIT NO. GR 140.3' 67-26 "' Check Appropriate Box' To Indicate Nature of NOtice, Re ~ort, or Other Data NOTICE OF INTENTION TO: ' ~UB~EQUENT IIPOIT OF: CTURr-TREAT '. I. . ULTI L C . · [ I I ' , I ' · I I .... Peer~mnl~l-~ rr~ ~--, J (NoT~: Report results of multiplecompletion on Well ,Other~ ~'~ ~-~ ~ ~a~ I' Completion or Reeompletion Reportand Log form.) z5 v~:aCalnz vnovosrv os CO>~PLZ~P~ZO~ ~i~rl~te~lT~t~nent details, and giro pertinent dates, including estimated dat~ of starting any proposed work. It is p~anned to plug and abandon the "G" Zone and recomplete wei~ in the Beaver Creek Gas Sands. Following are the plans of abandonment and recompletion. 1. Set blanking plug "Q" Nipple @ 14,691'. Permanent packer set @ 14,680'. 2. Spot 200' cement plug from 14.,680" to 14,480'. 3. Set bridge plug @ 11,950' - ll.l#/Gal, mud between bridge plug and cement @ 14,480'. 4. Spot 200' cement plug from 11,950' to 11,750'. 5. Spot cement plug. from 8,700' to 8,500'. Liner lap @ 8,616'. Mud from 8,700' to 11,750'. 6. Set bridge plug @ 5,600'. Mud from 5,600' to 8,500'. 7. Displace hole down to 5,600' with diesel. 8. Set production packer @ 5,050' with 3-1/2" tubing. 9. Install x-mas tree. MAY DIVISION OF OIL AND GAS (SEE ATT~1') SHEET~ .~ ANCHORAGE '6. I ,ereby ~y ~h.t th./lr,g~ t~ tr,. ,., S~D /~1~-~1~ t~/~~-~- ~" ~ O~rac~on~ S~per~nCend~nC ~ ~y 23 APPROVED BY' TITLE ' DATE co~m~o~s o~ ~~ ~ · S~ Instructions On Reverse Side ,.Approved' Copy 10. Perforate Beaver Creek Gas Sands from approximately 5,155' to 5,224'. 11. Unload and clean well to separator. 12.' Install back pressure valve in tree. 13. Move rig off location. Verbal approval received as per telephone conversation between Doyle L. Jones and W. C. Wunnicke on April 20, 1974. DIVI$1CN ~. t- C'II, /'.ND OAS ANCHORAGE , · ) RE-ENTEREL 590'S~ I979'W £r NE cot. T6N, PO. OW, Sec. 3, SM g~m. (If Dk<fi~naD APl ff50-133-20021 To,O mpm 15, 697' P. edlSll Vertical Depth PBD 11.~, 8 8 O' C.a~it~ ~'~modac~a 3MMcf/D fr per£s (2HPF) ~¢ 52h.h'-5230', 5220'-5215', 52!5'-5185', )erfd 3 'G" Zones (see PerL); aN~pts to ]prodace ~om "G*' runes unsuccess~. ~m~,.,.o. ad back ~d recompleted as gas shut-in {')zilld. nally drilled and completed as a gas well !.967 (see tickea g~85). Dzill Stem. Te~ts · Form No. P---4 ]lEV. 9.30-67 STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE SUBMIT II'q" DUPLICATE MONTHLY REPORT OF ~D.RILLING AND WORKOVER OPERATIONS ~. NAME OF OPERATOR Marathon Oil Company 3. ADDRESS OF OPEP~TOR P. 0. Box 2380, Anchorage, AK 99510 LOCA~ON OF WF-J~L Surface: 590' FNL, 1979' FEL, Sec. 3, T6N, R10W, SM '5. AP1 NUA{ERiCAL CODE 50-133-20021 LF_~ASE DESIGNATION A~'D SE1RIAL NO. A-028118 ?. IF INDIA]~, ALOi i~ OR TRIBE NANIE 8. LENIT,F-42RA~ OR LEASE NAA4E Beaver Creek Unit 9. W~:i.T, NO, 2 10. FY~-T-r~ AND POOL, OR WILDCAT Beaver Creek - "G" Zone 11. SEC., T,, R., M., (BO~FOM HOLE OB.rF_~rnrS) (Straight Hole) 12. PERMIT NO. 67-26 13. REPORT TOTAL DKPTH AT END oF MONTH. CI-IA~N'GES IN HOLE SIZE, CASING AN]2) CE1ViENTING JOBS INCLUDING DEPTH SET AN~ VOLI/MES USED. pERFORATIONS. TESTS AND ttESULTS, FISHING JOB~. JLrNK IN HOLE A~ID SIDE-TRACKED HOLE AND A2~Y OTHER SIGNIFICANT CI-IAN.~ES IN HOI~ CONDITIONS. BEAVER CREEK UNIT, WELL #2, RECOMPLETION -APRIL, 1974 The workover at Beaver Creek Well #2 will temporarily abandon the Beaver Creek Gas Sands and recomplete for a "G" Zone test. 4/1-6 After cementing squeeze perfs from 14,660'-14,661' with 640 sacks in 4 jobs, tested these perfs to 6000 psi - O.K. 4/7-14 Located casing leak in 7" liner between 12,204' and 12,300'. Set bridge plug at 12,403' and cement retainer at 12,119', but retainer leaked. Set a second retainer at 12,029' and squeezed casing leak with 180 sacks. Drilled out cement retainers and bridge plug and cleaned out well to 14,880' PBTD. 4/15-18 4/19-23 4/24 Set a permanent production packer at 14,680' and a hydrostatic packer at 11,990' on 3-1/2" O.D. tubing to isolate casing leaks. Removed BOPE, in- stalled x-mas tree, and tested to 5,000 psi - O.K. Displaced the mud with diesel, but left mud between packers in annulus. Ran Gamma Ray Log for correlation and perforated the "G" Zone with 2 holes/ft. with a thru-tubing gun from 14,.780'-14,795' (15'). Gas lifted well with no recovery. Pressured up on perfs to 6,100 psi, but couldn't pump in. Perforated lower "G" Zone with 2 holes/ft, thru-tubing from 14,844'-14,866' (22') and reperforated 14,780' to 14,795' with 2 shots/ft. Gas lifted well with no recovery. 4/25-26 Perforated upper "G" Zone with 2 holes/ft, thru-tubing from 14,715'-14,725' (20'). Gas lifted well and recovered 10 BBLS of emulsified crude oil in 2 days. (SEE ATTA~}IED SH ~ET) NOTE--J~eport on this. rm is required for each calendar month, regardless of the status of operat~ an~lF~rn~t~ bi~fll~d d/l/~ d~,c~ with the Division of Mines & Minerals bythe 15th of the succeeding m°nth, unless °the~ise directed' ~ ~ ~ ~ ~ ~ L~~ t AY ! 6 i974 BEAVER CREEK UNIT, WELL #2, RECOMPLETION - APRIL, 1974 (Cont'd.) 4/27-30 Killed well with mud, removed x-mas tree, installed BOPE, and tested to 5,000 psi - O.K. Pulled hydrostatic packer loose and pulled tubing. Ran in hole with driil pipe and began milling on. permanent packer at 14,680'. On 4/30/74 milling on packer to clean out hole in preparation to reperforate with casing guns. MAY ?. 6 I974 Union Oil Company C'~lifornia union April 15, 1974 Mr. Homer Burrell State of Alaska Department of Natural Resources Oil ~ Gas Division 5001 Porcupine Drive Anchorage, Alaska 99S04 TBUS G-20 (23-28) TBUS K-19 (32-19) TBUS D- 26 (ii- s) · 'BEAVER CREEK UNIT #2 Dear Mr. Burrell: Enclosed are the Monthly Report of Drilling Operations for G-20 (25-.28) on the Grayling Platform, 'K-19 (52-19) on the King Salmon Platform, D-26 (II-S) on the Dolly Varden Platform and Beaver Creek Unit Well #2. Very truly yours, R. Cal!ender District Drilling Supt. sk Enclosures (8) CC: Marathon Arco Amoco Socal Skelly Phillips ail encl. G-20, K-19, D-26 G-20, K-19, D-26 G-20, K-19, D-26 G-20, K-19, D-26 G-20, K-19, D-26 Form No. P---4 REV. 9-20-67 STATE Or ALASKA OIL AND GAS CONSERVATION COMMITTEE SUBMrT LN- DL~PLICATE API NL~IERICAL CODE 50-133~20021 LEASE DESiGNA'~ION AND SEt~IAL NO MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS A-028118 1. 7,IFINDIAIN~, ALOT'I-EE,OI~TRIBE NAME 0IL ~" i~ LL ~WELL OTHER 2. NAME OF OPEP,.~TOR 8. L.~NIT,F.,kRA~[ OR LEASE NAME Marathon Oil Company Beaver Creek Unit 3.ADDRESS OF OPERATOR 9.WELL NO P. O. Box 2380 Anchorage, Alaska 99510 2 10. FIELD A-~D POOL. OR WILDCAT 4. LOCATION OF WELL Surface: 590' FNL, 1979' FEL, Sec. 3, T6N, RIOW, S.M. Beaver Creek- "G" Zone 11. SEC., T., i~., M., (BO'I'TOM HOI..E o~.mc~rrw) (Straight Hole) 12. PIgILM IT 67-26 13. REPORT TOTAL DEPTH AT F. ND OF MONTH CI-IAx%GES IN HOLE SIZE, CASING A/gD C~%IENTING JOBS INCLUDING DEPTH SET AN~D VOLLrMES USED, PERFORATIONS TE. STSA2NFDI:LESULTS. FISHING JOB~, JUNK LN HOLE A.ND SIDE-TRACKED HOLE AND A. NYOTI41~t~ SIGNIFICANT C-H-A_NGF-,S INt{OL~ CONDITIONS. BEAVER CREEK UNIT, WELL #2, RECOMPLETION - MARCH, 1974 The wockover at Beaver Creek Well #2 will temporarily abandon the Beaver Creek gas sands and recomplete for a "G" Zone test. 3/8-12 Initiated workover operations on Well #2 at 12'01 a.m., 3/8/74. Mixed mud, circulated and killed well, and installed BOPE. Tested BOPE to 5,000 psi and bag to 3,000 psi. Pulled packer and tubing. 3/13-19 Drilled bridge plug at 5,267' and squeezed off perforations from 5,324'-5,344' (shot in error in 1967) with 75 sacks cement. Drilled out bridge plug at 5,624' and cleaned out to top of 7" liner at 8,609'. 3/20-22 Ran 84 JTS of 7" OD, 29#, x-line tie-back liner from 4,974' to 8,615' (6 ft tie-back lap) and cemented with 170 sacks. Liner covers Beaver Creek gas perfs 5,-155' - 5,244'. Ran 3 packers to assure liner seal. Ran dry test with DST tool - liner top tested OK. 3/23-.26 Cleaned out and .recovered wireline tools left in well in 1967. Milled out packer at 14,811'. Shot 4 squeeze holes from 14,902' to 14,903' and cemented with 190 sacks leaving plug-backTDat 14,880'. 3/27-31 Shot 4 holes from 14,660' to 14,661' and squeezed with 640 sacks of cement in 4 jobs. Preparing to clean-out and test squeeze on 3/31/74. AFH '..' 5' i974' ' =~ Area Superintendent ~.,.~ 4/11/74 N;W~Rep'ort with the Division of Mines & Minerals by the lSth of the succeeding month, unless otherwise directed. ARATH C~ MARATHON OIL COMPANY PAODUCTION-UNITF:D STATES AND CANADA ANCHORAGE DIVISION P.O. 8DX 2380 ANCHDRAGIE , AI. ASKA Ei9510 November 20, 1973 U. S. Geological Survey P. O. Box 259 Anchorage, Alaska. 99510 Attention: Mr. Rodney A. Smith Oil & Gas Supervisor Alaska Area Gentlemen: Ks you requested in your letter of October 25, 1973, I am attaching a schedule of our proposed test program for Beaver Creek Wells #2 and #4. After recompletion of BC ~2, about 36 days will be needed for production and buildup tests on BC #2. If these tests show a pulse test to be needed and feasible, an additional period of at least 30 days will be required to generate the pulses in BC #2 and detect them in the shut-in BC #4 well. For the reasons given in my letter dated October 19, 1973, we believe it is desirable to continue producing BC #4 until BC #2 is recompleted and tested. However, at the time that letter was written, we expected to have BC #2 recompleted by December. The. strike by the Alaska Drillers and Roughnecks Association has delayed the recompletion for an indefinite period. Even if the strike would end tomorrow, it would probably be mid-January before the workover can be co.mpleted. At that time of the year, we anticipate that the frac job might have..to be delayed because of extreme c°ld weather. To be realistic, the strike and the weather could delay the recompletion and testing until next spring. / o/3 JA ['I o I974 1~ I' ~ U', S. Geological Survey Attention: Mr. Rodney A. Smith November 20, 1973 · Page 2 · As you are aware, we have been investigating the feasi- bility of injecting excess solution gas into the Sterling gas sand in BC #lA. Although our study is not yet completed, the results to date are encouraging.. Core Lab has run a dew pOint test on a Beaver Creek gas sample. The test showed no liquid dropout at reservoir conditions. The question still remains as to whether this was a representative gas sample or if variations in operating conditions might at times result in liquid dropout. We feel certain enough that injection will prove to be feasible that we have already ordered the required compressor cylinder. Delivery was originally. promised for December, 1973. We:called the manufacturer today in an attempt to expedite delivery. We were told that dUe to an unusually heavy'work load, the delivery date has slipped to early 1974. We have asked our central purchasing department to try in every way possible to accelerate the delivery and also to try to find a suitable used. cylinder. If we can obtain a cylinder bY mid-January, we will be able to inject the excess gas within a week to ten days later. We request permission to continue producing BC #4 and flaring the excesS solution gas until the gas injection facilities are completed. I assure you that we will make every effort to .complete the installation as soon as possible. After injection is started, a minimum safety pilot flare will be necessary. We request .permission to use up to 300 MCFD for that purpose. We have not yet obtained the final pressure buildup test that you requested. We had planned to run the test about two weeks ago but the compressor went down ahead of schedule due to a seized third stage cylinder. The compressor was repaired and the well placed on reduced flow on Nove~er 14 after being shut in for eight days. · After the well was returned to' service, paraffin deposits were cut out of the tubing over an interval from 7,600 to 10,379 feet. Paraffin cutting was completed and the well placed on maxim~ producing rate on November 19. The producing rate has not yet stabilized so the ef~~o~ ~ ~ ~ ~ the paraffin removal can not yet be determined.~~ ~ ~ U~ ~ ~ · . Yours ~ery/ruly, ~l'!~ t~ ~/~~ ~ PT~ ~7~0~5 Acting Division Operations Manager "% TIME-DAYS GUM TEST I $ I 4 I 18 14 22. 4 26 4 RECOMPLETE PERFORATE ;~4-HR ORIGINAL PRESSURE RECORD PURPOSE OF T~..~.) BEAVER CREEK 4 BUILDUP TEST FRAC AS PER FRAC DESIGN IPRODUCE FOR 2 WEEKSJ L RES. PRESSURE .... WELL FLOWING I~ INTERFERENCE PRE-FRAC EVALUATION I ! ! I NECESSARY FOR FRAC EVALUA~ON I iANALYZE · ALL TESTS KEEP WELL FLOWING WELL FLOWING 127 67 137 77 142 82 I0 ~=.<~'rEST .EC~SAR¥ '~ I~ YES I DESIGN PULSE TEST CONDUCT PULSE TEST LOW Kh HIGH Kh ANALYZE Aid. TESTS .ESE.VO,. coNT,.urr¥ " "'--~'--1 INTER-WELL PROPERTIE.~ - SHUTIN I-WEEK BEFORE PULSE IN 2 6 RECORD PRESSURE-T I M E ' DATA PULSE TEST PRESSURE-TIME DATA J I ANALYZE TEST DATAi ~{ CoNcLUsIoNS 8~ · · RECOMMENDATIONS ,IA ['! 7{ ,;'~; I974 A TESTING PROGRAM FOR ,O"r' h~ ~ 7,~)~ BEAVER CREEK OIL FIELD UNITED STATES DEPARTMENT OF 'file INTERIOR GEOLOGICAL SURVEY P.O. Box 259 Anchorage, Alaska 99510 Marathon Oil Company P.O. Box 2380 Anchorage, Alaska 99510 197~3 October 25 ,.~; i ~ r- ...i Attn: Mr. W. L. Kinney Acting Division Operations Manager Gentlemen: Attached is an approved copy of your plan to recomplete and test Beaver Creek Unit well No. 2. In addition to the proposed work on well No. 2,. yoor'October 12 and October 19, 1973 letters request approval to continue producing Beaver Creek Unit well No. 4 until the No. 2 well is' completed, ~to test well No. 2 for a reasonable 'period of time and to further produce No. 4 for pressure interference tests. Excess solution gas wouId be flared. As we understand your plan, we see no objection to the continued pro- duction of Unit well No. 4 for an additional limited period, a reason- able test period for well No. 2 and limited production for pressure interference tests. However, we ask that you furnish the detailed. program for testing well No. 2, continued testing of well No. 4, and the pressure interference tests as soon as possible for our review and final consideration of your proposal. So as to prevent the shut-in of well No. 4 while you are finalizing your plans, the producing test period for well No. 4 is hereby extended until November 22, 1973. As you know, we are much concerned about the flaring and waste of excess solution gas and we cannot allow the was~ of gas over and above that necessary for initial well evaluation tests. It now appears that the added production history from well No. 4 and initial test data from well No. 2 should furnish sufficient information for a reasonably reliable evaluation. We are hopeful that your investigation into the feasibility of injection of the excess solution gas shOws that reinjection is a workable solution. We urge you to initiate studies and plans necessary for beneficial utili- zation or conservation of the excess gas since continued flaring beyond that deemed necessary for initial testing and evaluation will not be permitted. If you have any questions on the above, please contact me. Sincerely yours, Attachment ,~ r. '-' .. ._.-~ ~-~-'~-""'~' ~odney A~, Smith Oil and Gas Supervisor Alaska Area · I' 1,,' . :'f 4"~ MARATHON OIL COMPANY PRODUCTION-UNITED STATES AND CANADA ANCHORA(~E DIVISION I=.O. BOX 2-~80 ANOHORAGE , ALASKA October 17, 1973 Mr. H. L. Burrell State of Alaska Department of Natural Resources Oil and Gas Division 3001 Porcupine Drive Anchorage, Alaska Dear Sir: I am enclosing completed Sundry Notice, Form P-3 on the proposed recompletion of Beaver Creek Well #2. For your information, I am also enclosing a letter to Mr. Rodney Smith, U. S. Geological Survey, in which we request permission to production test Beaver Creek #2 following recompletion, and to continue production testing of Beaver Creek #4. Yours very truly, ~ C. F. Ferguson Division Petroleum Engineer Enclosures Form P--3 E_EV. 9-30-6 9 S~abrntt "Intentions" in Triplicate & "Subsequent Reports" in Duplicate STATE O'F ALASKA OIL AND GAS CONSERVATION: COMMIYI'EE SUNDRY NOTICES AND REPORTS ON WELLS (Do not use this form for proposals to drill or to deepen Use "APP-LICATION 'FOR [~'ER/IV~iT-~' 'for such 'p~o~osal-~) AP1 NU1VIF_A~CAL CODE 6. LEA~E DESIGNATION A.ND SERIAL NO. A-028118 1. ?. IF IN'DIAN, A3.,LOTTF_2~ OR TRIBE NAME OIL ~'~ GAS [] WELL WELL 0THEB 2. NAME OF OPERATOR 8. UNIT, FARM OR LEASE NAME Marathon 0il Company Beaver Creek Unit 3. ADDRESS OF OPERATOR P. O. Box 2380, Anchorage, Alaska 99510 4. LOCATION OF WELL At surface 590'S, 1979'W, NE Corner, T6N, R10W, SM 9. WELL NO. 2 10. FIELD AND POOL, OR WILDCAT Beaver Creek - G Zone 11. SEC., T., R., M., (BOTTOM HOLE OBJECTIVE) Straight Hole 13. ELEVATIONS (Show whether DF, RT, GR, etc. 12. PER1VIIT GR 140.3' 67-26 I4. Check Appropriate Box To I,ncl~cate N, ature of N~ti'c'e, Re ~ort, or Other Dnt*a NOTICE OF INTENTION TO: TEST WATER SHUT-OFF ] I PULL OR ALTER CASINO FRACTURE TREAT MULTIPLE COMPLETE SHOOT OR ACIDIZE ABANDON* REPAIR WELL CHANGE PLAlV8 ,Other) Test New Zone 8UBEEQUENT REPORT OF: FRACTURE TREATMENT ALTERING CABIN0 SHOOTING OR ACIDIZING ~ ABANDONMENT* (Other) (NOTE: Report results of multiple completion on Well Completion or Reeompletion Report and Log form.) 15. DESCRIBE PROPOSED OR COMPLETED OPERATIONS (Clearly state all pertinent details, and give pertinent dates, including estimated date of starting any proposed work. It is proposed to initiate operations approximately November 1, 1975, to temporarily abandon the existing Beaver Creek gas sand completion using a tie-back 7" liner. The well will then be cleaned out to 14,950' and the G Zone oil sands tested and stimulated by a sand frac- turing treatment. A detailed workover procedure, proposed blow out equipment assembly and schematic diagrams of existing and proposed completion assemblys are attached. CONDITIONS OF APPROVAL, IF A~: TITLE Area Superintendent TITLE See Instructions On Reverse Side DATE 10-12-73 Approved Copy Returned 0'~ ' 0 9/21/75 WORKOVER PROCEDURE BEAVER CREEK NO. 2 Rig up on location 1. Install lubricator - RIH with Otis wireline and open circulating sleeve at 5,037'. 2. Install choke on tubing and kill well by pumping 10 PPG fresh water base mud down annulus to reverse circulate. 3. Install BP valve, nipple down tree, install 10", S,000# BOPE. 4. 'Pull and lay down 3-1/2" tubing and Guiberson RH-1 packer {70,000# required to shear packer). S. RIH with 3-1/2" D.P., 8-1/2, bit, clean out to S,290', drill HOWCO cast iron bridge plug, and clean out $,644'. 6. RIH with a cement retainer and set at 5,500', cement squeeze perforations S,324'~S,344'. 7. RIH with 8-1/2" bit and drill out cement squeeze to S,600'. 8. RIH with a multiple flow DST tool and set at $,300'. Dry test the squeezed perfs with 1,000 psi differential to the wellbore. Then wit'h the tool open, pressure test 'to 2,000 psi surface pressure. 9. RIH with 8-1/2" bit, drill cast iron bridge plug at S,644', and clean out to8,34S'. Drill cement from 8,345' to 7" liner top at 8,S94', run 9-S/8" casing scraper to 8,S94'. 10. RIH with a S-7/8" bit and drill out cement plug in liner to 8,700'. 11. Run Brown Oil Tool polish mill and dress liner receptacle at 8,594', circulate hole clean. 12. Run 7" tie back liner from 8,594' to $,000' with a screw- set packer on top, one hydraulic packer a joint from top, and a second hydraulic packer at about S,290' to isolate the gas zones. 13. Cement liner with neat slurry from 8,594' to 6,S00' using approximately 290 sacks of neat class G (no excess). Stab into tie back receptacle and set packers. 14. RIH with DST tool set at 4,500'. Dry test liner for gas leaks with 2,000 psi differential to the wellbore. P.O.H. 15. Pressure test casing to 3,500 psi. 16. Clean out liner to 14,265'. Drill cement plug from. 14,265' to 14,410'. Increase mud weight to ll.S PPG. Clean out to 14,610' and drill cement plug from 14,610' to 14,770'. Clean out to 14,795'. 17. Attempt to retrieve wire line fish at 14,795' if not in hard cement. Attempt to mill over junk and Guiberson AGT drillable packer set at 14,812'. Retrieve packer or push below 14,950'. If unsuccessful in removing packer, proceed to Step 20 but shoot upper set of perforations 14,750'-14,758' only (See Step 27), and proceed with completion eliminating lower perfs from 14,836' to 14,844'. 18. After removing packer, make a 5-7/8" bit and 7" scraper run to 14,950', circulate hole clean. 19. Set wireline bridge plug at 14,910!. 20. Perforate 4 squeeze holes ~t 14,320'. 21. RIH with RTTS and set at 14,270'. Block squeeze for zone location. · 22. Drill out and scrape perforations. Pressure test squeeze perfs to 3,000 psi. 23. RIH with. DP and spot 35 BBL diesel from 14,910' to 14,000' . 24. Run a permanent packer with a push-out plug on wireline and set at 14,450'. 25. Run production tubing string with gas lift mandrels closed. Space out, pick up, and circulate hole clean with diesel. Land tubing in packer at 14,450'. 26. Install 10,000 psi frac tree. 27. Perforate through tubing 14,750'-14,758' (8 holes) and 14,836'-14,844' (8 holes). 28. Check for fluid entry and skid rig approximately S0' from the wellhead. 29. Run BHP survey. 30. Frac through tubing as per frac design. 31. Ri~I with wireline and check for fill. · 32. Replace frac tree with $,000 psi production tree. Put well on test. 33. Open gas lift mandrel sleeves and put well on gas lift. .34. Production test and run Blip buildup for frac evaluation. 3S. Release rig to 7-day standby. ! 14,Joo - .............. p~,,- '- .... ls,~o8 ................... ('~ .................. ~,z4s,- .......... _! I ! - C. wm%ev'r-,, AG-T pi,.,,' - 4" o.w. ~_.~-~,o..,-T'u~e. - 27~'' ~s I ~4. T~O. P~p ~ o E~E)8~4. Tb9. - 2vl~'~ ~o~pl,~ -- p. ~:'r.D. ~ o, . I.ZI 4~oo .-/-o ~ o , croo . 3 %" q, 2 ~ g- ,~o ~u f~'v-~,ss / o ooo' -/o / 4., Z 85 # o . · · . i 700 · 2.OO I ! I I I I I i !! MARATHON O!/ COMPANY PRODUCTION-UNITED STATES AND CANADA ANCHORAGE DIVISION P,O. BOX 2380 ... . . - ' ANCHORAGE,ALASKA 99510 _-. · .... . ' - · - . . -_ ........ -. . . .... - - . -. U. S, 'Geological SUrvey P. 0. Box .259 ~chora~e~ ~laska ~510 Dear Sir-: In your letter dated May 15, 1973, you granted permission, subject to certain limitations, to conduct a four-month production testing' program on Beaver Creek Well 94 in order to determine the economic feasibility of further development. The attached graph of cumulative production versus daily production rate indicateS recoverable reserves from BC ~4 of about 1,300,000 barrels at an asSumed economic limit of 500 BOPD. The reserves would be increased further if operating expenses can be reduced to permit a lower economic limit. In comparison, the limited production data prior to the present test showed that recoverable reserves could be as low as 420,000 barrels. Even 'though .the four-month.test period is nOt-yet completed, we have received sufficient--encouragement from the results to date-to be willing'~to proceed with the next"step 'of..~the development'Program, We propose to recomplete Beaver Creek Well ~2, presently a shut-in gas well completed in the Sterling Gas Sands, to an oil producer in the G Zone. Further, as part of the workover we plan a sand fracture stimulation on the tight portions of the reservoir. A detailed workover procedure, proposed blow- out equipment assembly and schematic diagrams of existing and proposed completion assemblies are shown on the attached Sundry Notice, Form 9-331. The purpose of the proposed recompletion is two-fold: ~ ~ .... ii-~ ::.~ , I:.. () .... ,. . , :~. i.~I?~~,'~ ; .'.~ ,.:'-";~ /;.!.!~ ~,.'. ~ ?;?;,,~ ~,.~ . . ..... Mr. Rodney Smith U. S. Geological Survey October 12, 1'973 Page 2 :.-The limited 'test data' tO' date indicates .that the tight Sands-' in' BC ~_4. are making .o~nlyl ~.~minor contribution' to ::.~:prodUctiOn. If these sands' can. 'be effectively fracture. ..i~_~ii.~_2..2-~/~qS~'~mulated~,~Tec°nomiCal!~!~ec°ye~able reserves could be Production testing of BC #2 and continued testing of BC #4 ~ill hopefUlly.indicate sufficient reserves to justify the drilling of new wells. The decision to drill a new 'well will be a major one. We must justify not only the approximate $1,500,000 cost per well for one or more new wells, but also the estimated $1,600,000 cost.of pipelines to transport the oil and gas. We respectfully request permission to continue producing BC #4 and to produce BC #2' for a period of time not to exceed six months following recompletion, until adequate production data has been obtained to confirm the reserves necessary to justify this major investment. We also request permission to flare the resulting solution gas in excess of fuel requirements. during this test period. . . W. L. KiJney (/ Acting Division Operations Manager Attachments Company Well ~eld CORE LABORATORIES, INC. Petroleum Reservoir Engineering DALLAS. 'TEXAS June I3, 1968 Page I of I ~le RFL 5099 Marathon Oil Company Formation Kenai "B" Beaver Creek No. 2 County Kenai Beaver Creek Unit State A la s ka HYDROCARBON ANALYSIS OF '. Separator , COMPONENT MOl. PER CENT · GAS SAMPLE GPM Hydrogen Sulfide Carbon Dioxide Nitrogen Methane Ethane Propane i~o-Butane n-Butane iso-Pentane n-Pentane Hexanes Heptanes plus Nil Trace 0068 99.20 0.11 0.01 Trace Trace Trace 'Trace .Nil Nil 100.00 0. 028 0. 003 00031 Calculated .gas gravity ( air = 1.000) = O. 557 Calculated gross heating value = 1004 BTU per cubic foot of dry gas at 14.696 psia at 60° F. Opened at 105 psig at 72°'F. Core Laboratories, Inc. Reservoir Fluid Analysis REC£IV[O J U L 11 1968 DIVISION OF MINES & MINI~ - ANcHORAGE P. L. Moses Manager f These analyses, opinions or interpretations are based on. observations and material supplied by the client to whom, and for whose exclusive and confidential use, this report is made. The interpretations or opinions expressed represent the Best judgment of Core Laboratories, Inc. (all errors and omissions excepted); but Core Laboratories, Inc. and its officers and employees, assume no responsibility and make no warranty or representations as to the productivity, proper opera- tion. or nrofitableness of anv oil. ~ or other mineral Well or sand in eonneeMon With which such report is used or relied u~on. l'Lih~ , ,-~...,-._ ,.~IL COMPAN'Y I:::~COL~CTiON - UNITED STATES AND CANADA 731 '°1" STREET Ray 27, 196~ Mr. W. J. Linton Supervisor U. S. Geological Survey P. O. Box 259 Anchorage, Alaska 99501 · Dear Mr. Linton- Attached is the open-flow potential test report for the Marathon Oil Company Beaver Creek Unit #2 well. Very truly yours,. / / . f./! , Thomas Wilson, Jr. District Exploration Manager TW/ap Attachment cc- T. J. Challoner-Anchorage R. C. Shelton-LA RECEIVED MAY 9 1968 I)IVI$ION OF MINES & MINEli~,~ ANCHORAGE MARATHON OIL COMPANY PROE)UOTION - UNITEI-) STATES ANE) OANAOA 731 ,,i,, STREET ANCHORAGE, ALASKA @9501 February 5, 1968 Department of Natural Resources Division of Mines and Minerals 3001 Porcupine Drive Anchorage, Alaska 99501 Gentlemen: Enclosed is one (1) copy of the Beaver Creek ~2 Well His tory. Yours truly, T. J. Challoner Dist. Operations Mgr. TJC/jk Encl. FEB 6 1968 DIVISION OF MINES & MINERALS ANCHORAGE: UNITED STATES DEPARTIVIENT OF THE INTERIOR GEOLOGICAL SURVEY l~orm ~pproved. Budget Bureau No. 42-R356.5. L^.o o~ac~ ......A.n_~ho_r_.a_g_e. .......... ~ .u,~E. .... .A_:.O._2._S.!!_S. ............ ~,,? .............. ~.e._a.y.e.r__.qr..e..e.k_.~ni t LESSEE'S MONTHLY REPORT OF OPERATIONS Alaska Kenai Pen. Borough Wildcat Well State .................................. Co~ty .................................... Field ..................................................................... Ti~e followin~ is a correct report of operations and production (incl~din~ drillin~ and prod~cin~ wells) for the montk of ....... _J__8__n__u__a__ry ..................... , 19._..6._8, ............................................................................ ~ · P O. Box 2380 Marathon Oil Company /l~ent s address ..... : ............................................................. Company ........... ~. .... ~. ....., ................................... Anchorage, Alaska 99501 S~. r~ed ............ /.~,.~:.-:,,~ : ..................................... Phrase 272-5417 -~ -, ..... ,:/ Reservoir Engineer ................................................................................... ,/~, e~6 8 l;~l;~ f. ............................. : ....................... SEC. AND r~Wp. RANGE NO. ]4or ~ 3/NE/NW I 6N, I 10W 2 I C~. F?. or GAS OALLONS Or DA~S BARREL0 OF O1~ ORAVITY OASOLINE Paoovc~ (In tho~&) RECOVERED J~ll static durijg month of JaQuary . )lVl$l~ O~ BARREI~ OF WATZE (It none, so state) 19t58. EI'VED 5 1968 · REMARKS (I[ drilling, depth; if shut down, cause; date and result of test for ~asoline. content Of ga~) no no Now~..~There were ...................................... run~ or 8ale8 of ofl~ ............................................. M cu. ft. of gaa sold~ no ............................................. runs or sales of gasoline during the month. (Write "no" where applicable.) No~.--Report on this form is required for each calendar month, regardless'of the status of operations, and must be filed in duplicate with the supervisor by the 6th of the succeeding month, unless otherwise directed by the supervisor. Forn~ 9-329 (January 19~) 16--26766-0U.m. GOV£R##ZNT I*IIINTiNG OfF'ICE , Re** aeaver Creek U~tt #2 Harethon Off Company, operator P. o. Box2380 Anchor~e ~ Ahslr~ 9950! and Lo~ (Fo~m 9-330) bare been received h this o£f~ee. ~ an oversiShe, stntlar copLns ~ere hOC nade of tho reverse ~tde s~ £onna~m rolm end s~ date-. ~ you ~Xy Very t~ty youro, Thomas R. lqaFshali~ Jr. Petroleum Supervisor MARATHON OIL COMPANY PRODUCTION - UNITED STATES AND CANADA 731 ,,I,, STREET~' ANCHORAGE, ALASKA 99501 January 8, 1968 State of Alaska Division of Mines and Minerals 3001 Porcupine Drive Anchorage, Alaska Atten: Mr. Thomas R. Marshall, Jr. Re' Beaver Creek Unit No. 2 Section 3, T. 6 N., R. l0 W., S.M. Gentlemen' In accordance with Section 2008 of the State of Alaska's Oil and Gas Conserva- tion Regulations, we wish to file the following logs: 1 Sepia and 1 Blueline - Lane Wells Induction Electrolog covering the interval from 2212 ft to 15,425 ft 1 Sepia and 1 Blueline - Schlumberger Induction Electric Log covering the interval from 8839 ft to 15,687 ft 1 Sepia and 1 Blueline - Complete Mud Log, prepared by Geologic Engineer- ing Service It is understood that American Stratigraphic Company has previously filed a complete set of samples of the well cuttings taken from said well. It is our desire that the information filed in connection with this well remain confi- dential for the 24 months after the filing period. MLL/ap Encl. Very truly yours /~i Morris L. Lowinan- Distmict Landman DIVISION O~ MINES & MINE~ ANCHO~GE / ~.:m 9-330 ',,,ev. 5-63) ED STATES SUBMIT IN D~. DEPARTM~-I~T OF THE INTERIOR GEOLOGICAL SURVEY 2-'~!¢_~,Ji r In- st ruL'~.~:' on rcverse side) Form approved. Budget Bureau No. 42-R355.5. 5. I,EASE DESIGNATION AND SERIAL NO. A-028118 6. IF INDIAN, ALLOTTEE OR TRIBE NAME WELL COMPLETION OR RECOMPLETiON REPORT AND LOG* TYP~. oF ,v~.LL:o,,. F1 ,,AS ~ Fl 7. UN,T AGREEMENT NA,E WELL-- WELL__ DRY__ Other b. TYPE OF COMPLETION: NEW ~ ~VORK ~] DE~;P' F~ PI, UG [~] .-~ DIFF. F~ WELl, OVER EN BACK RES. VR. Other 2. NAME OF OPERATOR Marathon 0il Company Beaver Creek Unit 8. FARM OR LEASE NAME Beaver Creek Unit 9. WELL NO. 3. Al)DRESS OF OPERATOR P 0 Box 2380, Anchorage, Alaska 4. LOCATION OF WELL (Report location clearly and in accordance'With any ~tate requiremgnts)* Atsurface 590' south and 1979' west of-'NE:'corner of Sec' 3, T6N , :..~:, ":, ':-~ R10W,: S.M. At top prod. interval reported below , Straight:hole: At total depth -*' Straight hole I-.~. PER, IT NO. DATE ISSUED - I State 67-26 I 6/9/67 99501 zo. 11. 12. FIELD AND POOL, OR ~ILDCAT Wi 1 dcat SEC, T., R.. M., OR BLOCK AND SURVEY OR AREA Sec 3, T6N, R10W, SM COUNTY OR 13. STATE PARISH Kenai Alaska 15. DATE SPUDDED 16. DATE T.O. REACHED 17. DATE COMPL. (Ready to prod.) 18. ELEVATIONS (DF, RI~B, RT, OR; RTe.)s ] 19. ELEV. CASINOHEAO 7/13/67 11/9/67 12/26/67..,: KB-155.1 GR-140.3 ' I 138.6 20. TOTAL DEPTH, MD & TVB 21, PLUG, BACK T.D., MD & ~ ] 22/-Ir MU.LTIPLE COMPL, : 23. INTERVALS ROTARY TOOLS CABLE TOOLS ' ~ -? HOW~ AfANY* · DRILLED BY ]5,697 MB 5,290 ~D -- ..... ' ~~ ~ .- X . 24. PRODUCrNG INTERVAL(S), OF THIS COMPLETION TOP, BOTTOM,UNAMEi.(MD AND TVD)s 5155-5220' MD Kenai Gas Sands m 5229-5244' MD ~.. 25.WAS DIRECTIONAL SURVEY MADE no 26. TYPE ELECTRIC AND OTHER LOGS RUN .. "J ' I 27. WAS WELL CORED IES, DIL, Sonici Density, Gamma Ra~, Continuous Dipmeter, Cement Bo~d no · 2S. CASING RECORD (R~port all strings set in well) CASINO SIZE 20' 13'-3/8" 9-5/8" WEIOHT( LB./FT. 941 ! _68 &272 _ 280.02 Z~ 26" 221 -I. i / .~! 17-i/2" 8835.14 '"*' 12-]'/4" CEMENTINO RECORD'. 525 sx 2000 sx 1370 sx AMOUNT PULLED 29. SIZE TOP (MD)'~ 7" 8594 5" 15415 ' LINER RECORD ... .~ BOTTOM (MD) 15,439 15,697 CEMENT*~, SCREEN (MD) SACKS !i(! I 650 - - 30. TUBING RECORD sIZE · 3-~/z DEPTH SET (MD) [ PACKER SET (MD) ,b]12. I5073 - 31. PERFORATION RECORD (.Interval, size and number) .Perforated various intervals from 5155' to 15,386~. See :'previous re0Orts_, for details. Intervals listed unde]r Item 24 perforated for production i2. ACID, SHOT. FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED . . 33.* . , PRODUCTION. DATE FIRST PRODUCTION DATE OF TEST I HOURS TESTED 12/26/67 1l-3/4 hrs IPRODUCTION METHOD (.Flowing, g,as~ liyt, L~umping--size and type o.f pump) ] WELL STATUS (Producing or .......... - ..... shut-in) Sli~t i n FLOW, TUBING FBE~S, [ CASINO PRESSURE 1625 ] packer 24-HOUR RATE [[]f. . ~.~ . _~ .~ - > . . ._.,. est.:. 5000 0' ,- ' ' TEST WITNESSED BY 'R E':C, [:.'IV F:'-D 34. DISPOSITION OF GAS (8old, usg~ lot yuel~ venteg, etc.) .... ~_:~ F1 ared :: "' :.;: -' 35. LISTOF ATTACHMENTS '-' . ,- no'ne '~ :'J ......... ' * *; ."~, ':' ". '-. I I .. 36. I hereby certify tha~ th.e )[~re~oin~ and attached information:is complete and correct as determined from all available records "//"/,' ' ' '"' "' ' gi o,v,s',o~ SIGNED ' ~-; -'" ..... ~'/' ~''-~ -; TITLE :"' . ...;.DATE _ ' ~(See-lnstructions and S~ces ~or Additional Data on Revere Side) ~enm'¢d: ~his form is designed for F:ubmit~Eng a complete and corree~ well coml)loE':~q ze [)o~% and log on all types of 1E~.ds and leases to either a Federal agency o~ ~ orate ,' or both, pursuant to applico, b!e Jfede~-al and/or State laws and .cefp.~latious. Any necessary sp~ial instructions co?.ce:~ming Che use of this form and tke n~?'~uber of copi~ to be submitted, particularly with ro}~Lud to local, ~:ea, of regional proccdures and practices, either are shown below or will b~ l:::su~ by, or may be obtained from, Uu} local Federal and/or State o~ace, o ~: :~ :,'~:~t'cuctions on ~ora~ ~2 and 24, and 33, below regacdi.,::.[~ ~;2po.~_'.~l~;o reports for separat~ completions. If not filed prior to the ;;t~ u~ th. is :;um,'m,.ry .record is submitted, eopizs o:f all currently available Iog':~ (drillers, geologists, sample and core analysis, all types electrk~, etc.), forma- tion and pressure tests, and directio;.xM surveys, should be attached hereto, to the extent required by applicable ~'ederal and/or State laws and regulations. All attachments should be listed on tlfis form, see item 35. D?~n 4: If there are ~o,..~ requirements, ~ocations on Federal or Indian land should be described in accordance with Federal r~luirem'ents. '.Consnfit local State or Federal o~ce for siteeific inst~metic,'s. . Dean ~: Indicate which elevation is used as referm~.ca (where not otherwise shown) for depth measuremen~ given in other 3paces on this form and ';n any attachments. ~?mus 2~ ¢~nd ~4: If. ~his well is compb.q:ed for separate production from more than one interval zone (multiple completion), so state in item 22, and in item 24 showy the producing interval, or mtmw.~.~s, top(s), bottom(s) and name(s) (if any) for only [he interval repor~z~ h~ item 83. Submit a separate report (page) on this form, adequately identified, for each additional interval to be separately produced, showing the additional data pertinent to such interval; ' . . _ l¢em 29: "Sacks Cement": Attaeh~l supplemental records for tiffs Well should show the details of any multiple staze cementing and the location ~f the coraenting tool. Den~ 53: Submit a separate comp!etlon report on thi~; [orm for each interval to be separately p~'oduced. (See instr~uction for items 22 and 24 above.) 37. S'UXiT]~[A[{Y Oi~' POROUS ZONlgS: S£IOW ALL IMPORTANT ZONES OF FOTH)S[TY AND CONTI~NTf~ T~{ERI~()F; CORED IN'2ERVAL8; AND ALL D. RiLI.-~T~5[ ~ESf~, INCI,UDI~O DBPTiI IN'L'NRZAL TIqSTED, CUSHION ~'537U), 'EiM?] TOOL OPEN, FLOWING AND SIiUT-tN PRESSURErg, AND RECOVERIES TOP ;4i-i; D~ISCRIPTI01'%', CONfL'EbT'fS, is;TO. G~]OLOGIC l.f AR KY~i~S ~'fEA8. Df',:. ;] { 'a8. Kenai B 'Zone . . . . 5i20 5312 1.4940 :":', ; U.S. GOVERN,',IENT, ,UHTING OFFICE: E'S3--O-fi:S353~ 31 I - 233 .~')ATE. , Ja.n. 1968 [~ /...~ 'i"l"lOl~ OiI COItali~ ,,~' FIELD Beaver crk uni.t :Y OF OIL OR GAS ¥ ", WELL NO. 2 STATE Alaska LEASE Beaver Creek ITn ~_~ PARISH COUNTY Kenai Borough ~ I ' E LEV' +155.1 ' SEC. 3 TWP. 6N R. 1 OW MEASUREMENTS TAKEN FROM fToP OF OiL STRING ~ ToP OF ROTARY TABLE GRD. OR MATi ELEV. +141 4 ' J E Fosher · HISTORY PRE.ARED BY ' ' ELEV.__+154. 1 ' TITLE Adv. Petroleum Engineer ELEV. +140. 3 ' 'It is of the greatest importance to have a complete history of the well. Use this form in reporting the history of all important operations at the well, together with the dates thereof, including size of hole, size and number of bits, complete description of casing, cementing, fishing or drilling difficulties, surveys, all tests, ali completion operations and procedure, etc. DATE 6/15- 7/7/67 7/8- 7/10 7/11- 7/12 7/13 7/14 7/15 7/16 7/17 7/18 o 7/19 Built road from Beaver Creek ~1 location, drilled water well, and prepared location. Waiting on rig to complete Beaver Creek ~l-A. Moving in and rigging up drilling equipment. TD 300' - Spudded at 8:15 p.m. 7/13/67. Drilled 12-1/4" hole to 300' TD 300' - Reamed 12-1/4" hole to 17-1/2" hole and reamed 17-1/2" hole to 26" hole. Ran 7 'jts 20" casing with shoe at 280'° Cemented with 525 sacks Class "G" cement with 2% CaCl2, 15~ slurry. Good cement returns to surface. 20" Casing Detail 7 jts 20" 94~ H-40 8rd STSC Csg 276.52' 0 - 276.52' G.L. 1 Baker Duplex Float Shoe 3.50' 276.52' - 280.02' G.L. 280.02' TD 300' - Installed 20" casinghead and tested with 1,000~, OK. Installed BOP equipment. TD 1433' - Tested casing and Hydril with 1,0009 for 30 minutes, OK. Drilled shoe and 12¼" hole to 1433'. TD 2235' - Drilled 12¼" hole to 2235'° Reamed 12¼". hole to 17½" hole from 300' to 1430'. TD 2235' - Reamed 12¼" hole to 17½" hole 1430' to 2235'. TD 2235' - Ran 53 jts 13-3/8" casing with float collar at 2166' and shoe at 2211', Cemented with 2000 sacks Class "G" Cement with 2% CaC12, 15~ slurry. Had~good. cement returns to surface. Bumped plug with 1350~. Float held OK. waited on cement 6 hours. Cut off casing. RECEIVED FEB 6 1968 DIVISION OF MINES & MINERA~ HIti::~ ?.Y OF OIL OR GAS FIELD WELL NO.. 2 STATE LEASE Beaver Creek Unit PARISH COUNTY BLOCK SEC. ELEV. ~ I toP OF Oil STRING I ELEV.~ MEASUREMENTS ~.ToP OF ROTARY TABLE__ ELEV. TAKEN FROM ~GRD. OR MAT. ELEV. HISTORY PREPARED BY ' TITLE TWP. R. It is of the greatest importance to have a complete history of the well. Use this form in reporting the history of all important operations at the well, together with the dates thereof, including size of hole, size and number of bits, complete description of casing, cementing, fishing or clriiling clifficulties, surveys, all tests, all completion operations and procedure, etc. DATE 1967 7/20 7/21 7/22 7/23 7/24- 8/3 . 8/4 8/5 8/6 8/7 8/8 8/9 13-3/8" casing. Detail RT to top casing 33 jts 13-3/8" 72~ N-80 8rd LT&C Csg 19 j ts 13-3/8" 68~ J-55 8rd LT&C Csg 1 Baker Float Collar 'l.jt 13-3/8" 68-~ J-55 8rd LT&C csg 1 Baker Guide Shoe Ail Casing Range 3 16'60' 1354.51' 794.52 ° 1.62' 41.82' 2.10' 2211.17' 0 - 16.60' 16.60' - 1371.11' 1371.11' - 2165.63' 2165.63' - 2167.25' 2167.25' - 2209.07' 2209.07' - 2211.17' TD 2235' -Welded on casinghead and tested with 1300~, OK. Tested casing and BOP's with 15009 for 15 minutes, OK. Drilled float collar and shoe. TD 4510' - Drilling. TD 5594' - Drilled ~12¼" hole to 5594'. Ran Lane Wells IES logging tool to 3950' where hit bridge. Unable to go deeper. Logged out of hole to have correlation log. Checked casing point at 2211', OK. TD 5954' - Ran in and circulated for two hours. Ran Lane Wells IES and Acoustic logs t© '5574'. Drilled ahead. TD 8638' - Drilling. TD 8848' - Drilled 12¼" hole to 8848'. Ran Lane Wells IES logging tool to 8417' where hit bridge. Pulled logging tool out of hole. TD 8848' - Ran in and Circulated 5 hours. Ran Lane Wells IES, Gamma Ray, Acoustic, and Caliper logs. · TD 8848' - Ran Lane Wells Dual Induction Log. Density tool stuck at 7,258'. Top of fish at 7,234'. Picked up o~ershot on drill pipe. Cut wire line at Surface and stripped drill pipe in hole. Latched onto fish, pulled wire line out of rope socket, and recovered fish. TD 8848' - Ran in, circulated and conditioned mud for 3½ hours. Ran density log from 5500' to 3500' and dipmeter from 8830' to 3500'. TD 8848' - Ran in hole and circulated for 6 hours. Commenced running '9-5/8" casing. TD 8848' - Ran 214 jts of 9-5/8" casing with Baker Differential Fillup Collar at 8790' and with Baker Float Shoe at 8835'. Cemented with 1370 sacks of Class "G" Cement with 1% CFR-2 and with 20 bbls of mud flush ahead of cement. Bumped plug with 2000~. %lta~ ~%U Q~' Had full returns throughout cementing job. R . FFR t~ 1QI~R ,DATE', HI~._, RY OF OIL OR GAS Wk .L FIELD WELL NO. STATE BLOCK 2 i I LEASE Beaver ~_r~ TT~ ~ ~_ SEC ........ TWP PARISH COUNTY, ELEV. ~ I ToP OF OIL STRING __ ELEV., HISTORY PREPARED BY MEASUREMENTS TOP OF ROTARY TABLE__ EIEV. TITLE TAKEN FROM [GRD. OR MAT. ELEV. It is of the greatest importance to have a complete history of the well. Use this form in reporting the history of all important operations at the. well, together with the dates thereof, including size of hole, size and number of bits, complete description of casing, cementing, fishing or drilling difficulties, surveys, all tests, all completion operations and procedure, etc. DATE 1967 8/10 8/11 8/12- 8/16 8/17 8/18- 9/10 9/11 ~9/12 9/13 9/14- 9/23 9/24- 9/28 9-5/8" casinq Detail KB to Top Casing 13.75' 1 jt 9-5/8" 47~ N-80 8rd LT&C Csg 22.77' 102 j ts 9-5/8" 40~ N,80 8rd LT&C Csg 4166.93' 31 jts 9-5/8" 43..5~ N-80 8rd LT&C Csg 1289.07' 40 j ts 9-5/8" 47~ N-80 8rd LT&C Csg 39 jts 9-5/8" 47~ S-95 8rd ST&C Csg 1 Baker Differential Fillup Collar 1 j t 9-5/8" 47~ S-95 8rd ST&C Csg 1 Baker Float Shoe 1665.05' 1632,12' 1.80' 41.85' 1.80' Ail Casing Range 3 8835.14 ' 0 - 13.75 13.75' - 36.52 36.52' - 4203.45 4203.45' - 5492.52 5492.52' - 7157.57 7157.57' - 8789.69 8789.69' - 8791.49' 8791.49' - 8833.34' 8833.34' - 8835.14' TD 8848' - Ran Lane Wells Cement Bond Log and found cement top at 3508'. Installed BOP equipment and tested blind rams with 3000~ for 15 minutes, OK. TD 9053' - Drilled float collar at 8790'. Tested hydril, pipe rams, and casing with 3000~ for 15 minutes,. OK. Drilled shoe at 8835' and cleaned hole to 8848'. Hole reduced at 8848' from 12¼" to 8½". Drilling ahead. TD 9915' - Drilling 8½" hole. TD 10,035' - Filled casing annulus between 9-5/8" and 13-3/8" csg with drill water. Attempted to pump into formation with 2300%. Unable to break formation down. Still have ample storage space for waste drill water in reserve pit. Drilling ahead. TD 13,246' - Drilling 8½" hole. TD 13,471' - Drilled 8L"~ hole to 13,471'. Circulating and conditioning hole. TD 13,471' - Measured drill, pipe in and out of hole, no correction. Circulated 5 hours 'with short trip of 10 stands. Preparing to log. TD 13,507' - Ran Lane-Wells Dual Induction and 'Acoustic logs. Drilling ahead on 8½" hole. TD 14,577' - Drilling 8½" hole. Replaced 3000' of Grade "E" drill pipe with Grade "G" drill pipe. TD 14,935' - Drilling 8½" hole. RECEIVED FEB 6 1968 , DATE_ . HIS. tRY OF OIL OR GAS W~.-L FIELD WEi'L NO.. 2 LEASE STATE Beaver Creek Unit PARISH COUNTY BLOCK SEC, i TWP MEASUREMENTS TAKEN FROM fToP OF Oil STRING ~ TOP OF ROTARY TABLE__ GRD. OR MAT, ELEV. ELEV. ELEV. ELEV. __ HISTORY PREPARED BY TITLE It is of the greatest importance to have a complete history of the well. Use this form in reporting the history of all important operations at the well, together with the dates thereof, including size of hole, size and number of bits, complete description of casing, cementing, fishing or drilling difficulties, surveys, all tests, all completion operations and procedure, etc. DATE 1967 9/29- 9/30 10/1- 10/3 10/4 10/5 zo/ 10/7 10/8 10/9 lO/lO lO/ll 10/12 10/13- lO/14 lO/15 10/16 TD 14,935' - circulated and conditioned hole for logging. Ran Lane- Wells IES log, Acoustic log, dipmeter, and sidewall cores. Fired 24 sidewalls shots and recovered 21. TD 15,186' - Drilling 8½" hole. Picked up 46 jts Grade "G" drill pipe. Now have approximatelY 4,185 feet of Grade "G" in string. TD 15,253' - Pipe torqued up while drilling at 15,253'. Tried to pull off bottom but pipe stuck. Bumper sub still working and have full circulation. TD 15,253' - Ran Dialog free point and found string free down to bit sub. Backed off at 15,218'. Left one drill collar, bit sub, and bit in hole. Total fish 35'. Ran in and screwed .into fish and started jarring. TD 15,253' - Recovered fish. Going in hole with bit. TD 15,260' - Commenced drilling and drilled 7' when bit hung up. Could not pick up drill pipe. Ran Dialog free point and found pipe partially stuck at 15,250'. Backed off at 15,226' leaving one drill collar, bit sub and bit in hole. Screwed into fish and started j arr ing. TD 15,260' - Recovered fish. Going in hole with bit. TD 15,317' - Drilled oz~,, o-2 hole with no hole problems. TD 15,388' - Drilling. TD 15,406' - Drilling 8½" hole. Tight spots at 10,000' to 10,500'. TD,15,431' -Drilled 8½" hole to 15,431'. Preparing to log. TD 15,431' - Ran Lane-Wells Dual Induction Log, Acoustic log, density IES log, and attempted to run dipmeter but tool was inoperative. Shot 25 sidewall cores and recovered 7 leaving 18 in hole. Ran in with bit and milled on sidewall cores for 2½ hours. TD 15,434' - Ran magnet and recovered a handful of iron. Ran bit and junk sub. Drilled.rough from 15,431' to 15,432'. Drilling smooth at 15,434'. TD 15,439' - Drilled o-2 hole to 15,439'. Conditioned hole for logging. RECEIVED . FEB,G 1968 FORM ,~,84 REV, · DATE. ' I~. ~THON OIL COMI=. '~Y HlS~l ~RY OF OIL OR GAS Wl~LL FIELD .... WELL NO. STATE MEASUREMENTS TAKEN FROM 2 LEASE Bea~er Creek Un~ t PARISH COUNTY. · ELEV. ~ 'TOP of Oil STRING i I ELEVi ~ .ToP OF ROTARY TABLE ~ ELEV. ~ GRD. OR MAT ELEV. ' BLOCK · . SEC ..... TWP..~ R ......... -. HISTORY PREPARED BY TITLE, it is of the greatest importance to have a complete history of the well. Use this form in reporting the history of ali important operations at the well, together with the dates thereof, including size of hole,' size and number .of bits, complete description of casing, cementing, fishing or drilling difficulties, surveys, ali tests, all completion operations and procedure, etc. DATE 1967 10/ 7- 10/18 10/19- 10/20 10/21- 10/22 10/23- 10/24 TD 15,439' - Ran Schlumberger IEs, dipmeter, sonic, and density log. Shot 30 sideWall cores. TD 15,439' - Ran 7" liner with top of liner packer at 8,594' and shoe at 15,439'. Dropped ball, set liner hanger, and .pulled into packer. Cemented with 650 sacks cement with 120% retarder and 650% friction reducer preceding cement With 282% mud sweep and 500 gallons of water. Good returns throughout job. 7" Liner Detail KB to Top Liner Packer 1 Brown type "SS" Packer 1 Brown "MC" Hydraulic Hanger 34 j ts 7" 29~ ~-80 X-line Rge 3 Csg 68 j ts 7" 29% P-110 X-line Rge 3 Csg 57 jts 7" 32% P-110 X"line Rge 3 Csg 1 Brown Landing Collar 1 jt 7" 32% P-110 X-line Rge 3 Csg 1 Baker Model "G" Diff. Fillup Shoe 8594.44' 8.87' 8594.44 10.96' 8603.31 1461.53 ' 8614.27 2956.45' 10,075.80 2360.39' 13,032.25 0.94' 15,392.64 43.04' 15,393.58 0 - 8594.44' - 8603.31 ' - 8614.27 ' -10,075.80 ' -13,032.25' -15,392.64 ' -15,393.58 ' -15,436.62' 2.38' 15,436.62 -15,439.00' 15,439.00' TD 15,439' - Ran Cement Bond Log; Gamma Ray and collar locator. Tagged PBTD at 15,390'. Top of cement at 13,800'. Perforated 15 ,158 ' -15 , 248~ 15,285 '-15,345', and 15,356'-15,386' with 4 jets per foot using Schlumberger 4" Hyperjet gun. Ran in hole with Halliburton DST tools and landed packer at 15,124'. Opened tool at 6:30 AM 10/23/67. When tool opened, mud dropped in annulus immediately with strong blow in drill pipe. TD 15,439 - Pulled DST tool. Recovered 8,100' of mud and 1,000' of water cushion. Found hydrospring valve had backed out of Halliburton test tool. Picked up new Halliburton test tool and went into hole. DST %1 - Perfs 15,158-15,248', 15,285-15,345' and 15,356-15,386'. Ran Halliburton test tools on 3½" and 4½- drill pipe with 1000' of water cushion. Set packer at 15,124'. Pressure gauges at 15,114' and 15,135' . Opened tool for 5 minutes. Had weak blow. closed tool for 2 hours and 5 minutes. Opened tool for 11 hours and 29 minutes. Had immediate weak blow, medium blow in ½ hour and strong blow in 1 hour remaining steady thereafter. Closed .tool for 3 hours. Reversed 8 bbl fresh water, 5 bbl muddy water, and 45 bbl 33 deg API oil RECEIVED FEB 6' 1968 FORM.,~484 R~V. 3;-63 Eft' , TNON OIL C MF- .... aY' HISTORY OF' Oil_ OR GAS WELL FIELD BLOCK WELL NOoi 2 .LEASE Deaver Creek I;n~ t SEC.. PARISH STATE COUNTY ~ ELEV..~ TWP. R. f ToP OF OIL. STRING __ ELEV.i_ HISTORY PREPARED BY MEASUREMENTSLToP OF ROTARY TABLE~ ELEV. TITLE TAKEN FROM [ ~ /[GRD. OR MAT, ' ELEV. It is of the greatest importance to ha~,e a complete history of the well. Use this form in reporting the history of all important operations at the well, together with the dates thereof, including size of hole, size and number of bits, complete description of casing, cementing, fishing or drilling difficulties, surveys, all tests, all completion operations and procedure, etc. DATE 1967 10/25 10/26- 10/28 10/29 10/30- 11/2 Top Gauge' Bo't. tom Gauge IHI~ 8789 psig IFP 1022 psig ICP 7529 psig FFP 3139 psig FCIP 6821' psig FHH * 8870 pslg 1321 pslg 7613 pslg 3220 ps~g 6959 ps ~g 8790 ps~g * - Chart time expired during FCIP. TD 15,439' - After three misruns, set Halliburton drillable magnesium bridge plug on Schlumberger wireline at 15,120'. Perforated 14,942-14,962', 14,964-14,974', 14,990-15,020, 15,033-15,058', 15,063-15,073', and 15,080-15,100' with 4 Schlumberger Hyperjets per foot. TD 15,439' -While going in hole, Halliburton DST tool opened pre- maturely at 11,610' filling the drill pipe with mud. Pulled out of 'hole. Laid down faulty tool. Picked up and ran new tool. DST %2 - Perfs 14,942-14,962', 14,964-14,974', 14,990-15,020', 15,033-15,058', 15,063-15,073' and 15,080-15,100'. Ran Halliburton ~" and 4½" drill pipe with 1000' of water cushion . test tools on o 2 Set packer at 14,907'. Pressure gauges at 14,887' amd 14,919'. Opened to°l for 5 minutes. Had weak blow. Closed tool for 2 hours and 5 minutes. Opened tool for 26½ hours. Good blow immediately, strong blow in 15 minutes. Gas to surface in 1 hour and 25 minutes. Blow decreased and was barely discernable after 26 hours. Closed tool for 3½ hours. Reversed 7 bbl water cushion, 3 bbl mud, and 138 bbl 35° API oil.. Top Gauge Bottom Gauge IHH IFP ICIP FFP FCIP FHH 8665 psig 8708 psig 957 psig 981 psig 7380 psig 7389 psig 4231 psig '5376 psig * 7135 psig * 8 549 ps ig * - Chart time expired. TD 15,455' - Drilled landing collar, cement, shoe, and 6" hole to 15,455' . TI) 15,620' - Drilling 6" hole. FEB 6 1968 FORMe484 REV. 3,--63 DAT--E ' ~ [V~--~THC:~N OIL HIS", JRY OF OIL OR GAS W~I FIELD WELL NO. STATE MEASUREMENTS TAKEN FROM BLOCK 2 LEASE Beaver Creek Unit SEC. TWP R. · PARISH COUNTY. 'ToP OF Oil STRING ELEV .... ELEV.- HISTORY PREPARED BY i .ToP OF ROTARY TABLE__ ELEV. TITLE GRD. OR MAT ELEV ...... It is of the greatest importance to have a complete history of the well. Use this form in reporting the history of all important operations at the well, together with the dates thereof, including size of hole, size and number of bits, complete description of casing, cementing, fishing or drilling difficulties, surveys, all tests, all completion operations and procedure, etc. DATE 1967 11/3- 11/4 11/5 11/6- 11/8 11/9 11/1o 11/11 11/12 TD 15,650' - Drilled 6" hole to 15,632'. DST $3 - Open hole 15,439-15,632'. Ran Halliburton test tools in 3½" and 4½" drill pipe with 1000' of water cushion. Set packer at 15,405'. Pressure gauges at 15,395' and 15,419'. Bottom slotted tail pipe at 15,419'. Opened tool for 5 minutes. Weak blow immediately. Closed tool for 3 hours and 5 minutes. Opened tool with no blow. Closed tool and opened bypass. Opened tool With very very weak blow. Closed tool and opened bypass twice more in an attempt to unplug tools with no success. Pulled packer loose after an open-flow period of 4 hours and 10 minutes. Did not take a final shut-in period. Recovered~ 7.4 bbl water cushion, 0.7 bbl muddy water, and 8.3 bbl mud. Tools and slots in tail pipe plugging throughout test. Top Gauge Bottom Gauqe IHH 8811 psig IFP * ICIP * FFP * FCIP - FHH * 8826 psig 7591 psig 18371 ps ig** 8810 psig * ',Unable to read. ** Questionable Drilled and washed bridges from 15,460-15,575'. No bridges from 15,575-15,600'. Drilled and washed bridges from 15,600-15,632'. Drilled 6" hole to 15,650'. TD 15,695' - Drilling 6" hole. TD 15,695' - Ran in hole to 15,640' when main input shaft in drawworks broke. Circulated with bit at 14,790'. Installed new shaft and bearing. TD 15,697' - Drilled 6" hole to 15,697'. Circulated and conditioned mud for logging. Ran Schlumberger IEee Sonic, and density logs. TD 15,697' - Shot 13 sidewall samples and recovered 10. Preparing to run 5" liner. TD 15,697' - Picked up 5" liner and ran in hole. Unable to get liner below 15,551'. Pulled liner out of· hole. TD 15,697' - Ran 6" reaming assembly and reamed from 15,4%9~,697'. Had to ream several tight spots' R ~ C ~ l¥ U F'ORM a, 84 REV. ~DATE z.._, ~? ~, THE:~N OIL HIS", JRY OF Oil OR GAS W -I FIELD WELL NO. 2 LEASE STATE Beaver Creek Unit PARISH COUNTY. BLOCK SEC. ELEV. ~ f ToP OF Oil STRING ELEV.~ MEASUREMENTS ~ToP OF ROTARY TABLE__ELEV.~ TAKEN FROM /GRD. OR MATi ELEV. HISTORY PREPARED BY TITLE .... TWP. R. It is of the greatest importance to have a complete history of the well. Use this form in reporting the history of all important operations at the well, together with the dates thereof, including size of hole, s|ze and number of bits, complete description of casing, cementing, fishing or drilling difficulties, surveys, all tests, all completion operations and procedure, etc. DATE 1967 12/13 11/14 11/15 11/16 11/17 11/18 11/19- 11/20 TD 15,697' - Ran 5" liner on drill pipe. Liner stopped at 15,555'. Pulled liner out of hole. Reamed hole from 15,439' to 15,697'. TD 15,697' - Ran 4½" liner on drill pipe. 15,555' . Liner would not go past ' z~" liner out of hole. Waiting on drill down TD 15,697 - Pulled ~2 liner tools. TD 15,697' -Waiting on drill down liner tool. TD 15,697?' - Ran 5" liner with landing collar at 15,652' and with bit on bottom of float shoe at 15,697'. Rotated string slightly to get through tight spot at 15,555'. Cemented with 41 sacks cement with two tenths of 1% retarder. Bumped plug with 25009. Plug held OK. 5" Liner Detail KB to top Liner Tools 1 Brown Liner Hanger 6 jts 5" OD 18~ FJ Hydril Liner 1 Brown Landing Collar 15,415.00' 3.31' 233.71' 0.74' 0-15,415.00' 15,415.00 '-15,418.31 ' 15,418.31'-15,652.02' 15,652.02 '-15,652.76' 1 jt 5'" OD 18~ FJ Hydril Liner 42.00' 15,652.76'-15,694.76' 1 Brown float shoe w/bit screwed in bottom :2. 22.'.... 15,694.76'-15,696.98' 15,696.98' PBTD 15,652' - Reversed 10 bbls of mud flush but no cement. Ran in hole and tagged PBTD at 15,652'. .. PBTD 15,652' - Ran Schlumberger collar locator and gamma ray correlation log. Perforated 5" liner with 4 jets per foot 15,452-15,537' and 15,560-15,585' (Schlumberger IES measurements). Ran Halliburton test tools on 3½" and 4½" drill pipe for DST ~4. DST ~4 perfs 15,452-15,537' and 15,560-15,585'. Ran Halliburton test tools on 3½" and 4½" drill pipe with 2500' of water cushion. Set packer at.15,401'. Pressure gauges at 15,391' and 15,408'. Bottom tail pipe at 15,412'. Opened tool for 5 minutes. Had weak blow. Closed tool for 3 hours. Opened tool for 10 'hours. Weak blow throughout. Closed tool for 3 hours. Reversed 2500' water cushion, 720' rathole mud, and 1125' saltwater slightly gas cut with scum of oil. R£CEIVEO FEB 6 1968 FORM 484 R~-V, 3--63 DATE ~ ~. ~7~i!::3t~ I~l~L C¢::31Vii=. ~Y HIS'i ~RY OF OIL ~OR GAS WP_AL WELL NO., STATE MEASUREMENTS TAKEN FROM LEASE Beaver Creek Unit PARISH , COUNTY BLOCK SEC. ~ ELEV. , fToP Of OIL'STRiNG ELEV, ~ TOP OF ROTARY TABLE~ ELEV. GRD. OR MAT.i ELEV. HISTORY PREPARED BY TITLE FIELD ,TWP R., it is of the greatest importance to have a complete history of the well. Use this form in reporting the history of ali important operations at the well, together with the dates thereof, including size of hole, size and number of bits, complete description of casing, cementing, fishing or drilling difficulties, surveys, all tests, ali completion operations and procedure, etc. DaTE 1967 11/21 11/22 11/23 11/24 11/25 ,TOp Gauge Bottom Gauge IHH 8499 psig '8504 psig IFP * * ICIP 7505 psig 7491 psig FFP 2058 psig 2030 psig FCIP 5925 psig 5891 psig FHH 8477 psig 8462 psig * Unable to read PBTD 15,407' - Ran Halliburton 7" drillable cast iron bridge plug and RTTS tool on drill pipe. Set bridge plug at 15,410', pulled up and set RTTS tool at 15,397'. Pressured on bridge plug with 10005 for 30 minutes, held OK'. Pulled up and set RTTS tool at 9,013', closed BOP, and pressured up on annulus with 10005 for 30 minutes to test 7" liner lap. Held OK. PBTD 15,407' Laid down all drill pipe. Picked up 6" bit, 2-7/8" OD 6.5~ N-80 8rd EUE tubing, and 3½" OD 9.2~ N-80 buttress tubing. PBTD 15,407' - Completed picking up 3½" OD tubing. Tagged P~TD 15,407'2 circulated and conditioned mud for 4 hours. PBTD 15,407' -Mixed 210 bbls of I0W salt water. Displaced mud in 7" liner with 105 salt water. Washed perforations in 7" liner several times. Pulled bit to 7000' and circulated and conditioned mud. Schlumberger ran 7" gauge ring and junk basket to 14,875'. Perforated Kenai gas sands 5155-5175' with 2 jets per foot. PBTD 15,407' - Ran and set a Guiberson AGT drillable packer with tail pipe including X-nipple on wireline at 14,812'. Ran in hole with seal assembly, 2-7/8" OD tubing, circulating valve (open), 10 gas lift valves with sliding sleeve mandrels, (6 bottom sleeves closed- upper 4 open), X-nipple, circulating valve (closed), a Guiberson RH-1 hydraulic packer, and 3½" OD buttress tubing above upper packer. Landed tubing in lower packer with 70005 of weight. Upper packer at 5,016'. Installed back pressure valve in tubing hanger. 3½" .and 2-7/8" Tubing Detail Elevation CIW Hanger 3~" Pup Joint N-80 Buttress 159 j ts 3½" Tbg. N-80 Buttress 3½" 8rd x 3½"Buttress X-over 9-5/8" PJqI Packer $2663 3½" 8rd x 2-7/8" 8rd X-over 3 jts 2-7/8" EUE 8rd N-80 Tbg 14.80 ' .70' 9.45' 4,990.01 ' .95' 6.80' .80' ' 0- 14.80' 14.80 '- 15.50' 15.50 '- 24.95 ' 24.95'- 5,014.96' 5,014.96'- 5,015.91' 5,015.91'- 5,022.71' 5,022.71'- 5,023.51' FORM 4~84 ~DATE" REV. 3--63 , ~ ~v~. ~THC:~[~ OIL HiS' i uRY OF OIL OR GAS WLll FIELD WELL NO. STATE MEASUREMENTS TAKEN FROM LEASE Beaver Creek Unit PARISH COUNTY BLOCK SEC. TWP Rei . i ELEV. ~ f toP OF OIL STRING i ELEV.. , TOP OF ROTARY TABLE ELEV. ~ GrD. OR MAT ELEV. HISTORY PREPARED BY TITLE It is of the greatest importance to have a complete history of the well. Use this form in reporting the history of all important operations at the well, together with the dates thereof, including size of hole, size and number of bits, complete description of casing, cementing, fishing or drilling difficulties, surveys, ali tests, all completion operations and procedure, etc. DATE 1967 11/26 11/27 USI Circulating Sleeve ~C10793 13 j ts 2-7/8" EUE 8rd N-80 Tbg Otis "X" Nipple 6 j ts 2-7/8" EUE 8rd N-80 Tbg USI GL Valve ~10 67 j ts 2-7/8" EUE 8rd N-80 Tbg USI GL Valve ~9 52 jts 2-7/8 EUE 8rd N-80 Tbg USI GL Valve ~8 44 jts 2-7/8" EUE 8rd N-80 Tbg 'USI GL Valve ~7 36 j ts 2-7/8" EUE 8rd N-80 Tbg USI GL Valve ~6 28 jts 2-7/8" EUE 8rd N-80 Tbg USI GL Valve ~5 24 j ts 2-7/8 EUE 8rd N-80 Tbg USI GL Valve ~4 17 j ts 2-7/8" EUE 8rd N-80 Tbg US I GL Valve ~3 15 j ts 2-7/8" EUE 8rd N-80 Tbg US I GL Valve ~2 10 j ts 2-7/8" EUE 8rd N'80 Tbg US I GL Valve ~1 2 j ts 2-7/8" EUE 8rd N-80 Tbg USI Circulating Sleeve ~C10792 1 jt 2-7/8" EUE 8rd N-80 Tbg Lo'cator Seal Assembly Type "AGT" Drillable'Packer 4" OD Extension Tube 4" x 2-7/8" EUE X-over 2-7/8" EUE 8rd Pup Joint N-80 Otis "X" Nipple 2-7/8" EUE 8rd Pup Joint N-80 2-7/8" EUE 8rd Coupling 2.90 399.51 .90 186.84 3.56 2,055.92 3.56 1,591.08 3.56 1,341.55 3.56 1,107.23 3.56 857.37 3.56 735.63 3.56 520.70 3.56 456.37 3.56 309.86 3.56 61.11 2°90 30.86 6.28 2.69 5.47 .88 5.74 .90 5.73 .45 5,115.33 5,118.23 5,517.74 5,518.64 5,705.48 5,709.04 7,764.96 7,768.52 9,359.60 9,363.16 10,704.71 10,708.27 11,815.50 11,819.06 12,676.43 12,679o99 13,415.62 13,419.18 13,939.88 13,943.44 14,399.81 14,403.37 14,713.23 14,716.79 14,777.90 14,780.80 In packer 14,811.66 14,814 14,819 14,820 14,826 14,827 14,833 '- 5, I__ 5, '-- 5, -- 5, -- 5, -- 7, -- 7, -- 9, -- 9, --10, --10, --11, --11, --12, --12, --13, '--13, --13, --13, --14, --14, --14, --14, --14, --14, ' --14, 118. 23 517 .74 518. 64 705.48 709.04 764. 96 768. 52' 359.60 363.16 704.71 708. 27 815.50 819.06 676.43 679.99' 415.62' 419.18 ' 939.88 ' 943.44 ' 399.81' 403. 37 ' 713. 23" 716.79' 777.90' 780.80' 811.66' '--14,814.35 ' o 35 '--14,819.82 ' °82 '--14,820.70' .70 '--14,826.44' .44 '--14,827.34' . 34-"--14,833.07 ' .07 '--14,833.52' PBTD 15,407' - Removed BOP equipment and installed Xmas tree. Tested X-mas tree with 5000~, OK. Displaced mud and salt water from annulus with fresh water by pumping down tubing and through lower cir- culating valves at 14,778'. PBTD 15,407' - Rigged up Lane Wells 5/16" electric wireline unit° Set Otis blanking plug in x-nipple at 5518'. Set Guiberson RH-1 hydraulic packer with 2300~. Packer set at 5,016'. Opened upper circulating valve at 5115'. Tubing pressure increased to 1000~. Tested upper packer with 1000~, held OK. Opened tubing to flow well to pit and pressure bled to zero in one minute. Unloaded approximately 30 bbls water in 5 hours. No increase in flow rate or no gas to the surface. Hemlock zone app,%r% ~o! b~ ~f~wing fluid FFR fi 1Qn~ FOR~484 REV. .DATE` ~.;: ~TH~::~ ~::~lL COi~l~ qY HIS". ~RY OF Oil OR GaS W~-L FIELD WELL NO. STATE BLOCK 2 LEASE Beaver Creek Unit SEC. PAriSH COUNTY. ELEV. ~ ~ToP Of Oil STRING i IELEV.. MEASUREMENTStToP OF ROTARY TABLE~ ELEV. TAKEN FROM [GRD. OR Mat ELEV .... HISTORY PREPARED BY. TITLE .... TWP .... R. It is of the greatest importance to have a complete history of the well. Use this form in reporting the history of all important operations at the well, together with the dates thereof, including size of hole, size and number of bits, complete description of casing, cementing, fishing or drilling difficulties, surveys, all tests, ali completion operations and procedure, etc. DATE 1967 11/28 11/29 11/30 12/1 12/2 12/3 12/4 12/5 through the lower circulating valve at 14,778' and pushing fluid through upper circulating valve at 5115'. Ran Lane-Wells wireline and pulled blanking plug at 5518'. Attempted to close lower circulating valve at 14,778'. Tools stopped at 10,330'. Pulled tools and ran gauge ring which stopped at 10,330'. Started out of hole with wireline tools and well started flowing gas. Wireline lubricator freezing. Laid down wireline tools. Shut-in tubing pressure 2000~. Opened well to pit with' flowing tubing pressure 1800~. Well flowing large slugs of water. Flare burning OK. PBTD 15,407' - Flowed gas zone to pit for 5 hours at the end of which well was still making a trace of water. Estimated flow rate 2600 MCF per day with flowing tubing pressure of 1800~ on ¼" choke. Closed upper circulating valve at 5115'. Shut-in tubing pressure of 1900~ bled to zero in 20 minutes. Ran 1-3/4" sinker bars to 14,780', tubing clear. Ran 2¼" OD Gauge ring to 14,780', working gauge ring from 10,300' to 12,576', and 14,181' to 14,716'. Cement scale in tubing. Oil and water to surface at midnight 11/28/67. Shut well in and closed lower circulating valve at 14,778'. Opened lower 6 sliding sleeves in gas lift mandrels. Shut-in tubing pressure 300~. Opened well to pit and pressure bled to zero in 10 minutes. Recovered 2 bbls of oil. Well flowing small stream of fluid, PBTD 15,407' - Flowed well to pit. Recovered an estimated 5 bbls of oil and 25 bbls of water during the 24-hour period. PBTD 15,407' - Rigged up and swabbed 15 bbls of oil and 25 bbls of water. PBTD 15,407' - Produced by gas lift 5 bbls of oil, 15 bbls of water · and 78 bbls of mud. PBTD 15,407' - Produced by gas lift 13 bbls of oil, 76 bbls of water and 15 bbls of mud. Shut in well to hookup separator° Tubing pressure built to 1800~. Separator freezing between heads. Will bypass separator. PBTD 15,407' - Had small gas blow for 10 hours. Produced 32 bbls of oil in 14 hours. Flowing in small heads of about 1 bbl per head with tubing pressure 50~ to zero after each head. No tail gas. API gravity 33.1° at 60°F. PBTD 15,407' - Produced 28 bbls of oil in small heads wJt~ ,t~ between heads varying from 15 minutes to 2 hours. Tu~~~s~r~0~ to zero after each head. No tail gas. FEB 6 1968 PBTD 15,407' -Shut in for pressure buildup. Pr_.e...s~~ · well and r s u,v,~,~,.- ~, . in 6~ hours Opened p e sure bled ~o zer~No~z~e minute. Flowed 5 bbls of oil and stopped. Shut well in. Pressure built FORI~ 484 I~i;:V. 3--63 DATE-i' ' I M*. ~THON OIL COM~_ ~IY HIS'iORY OF OIL OR GAS WELL FIELD WELL NO. STATE BLOCK 2 LEASE Beaver Creek Unit SEC .... TWP R. PARISH COUNTY, ELEV. ~ I ToP Of OIL STRING I ElEV. HISTORY PREPARED BY MEASUREMENTS TOP OF ROTARY TABLE__ ELEV. TITLE TAKEN FROM [GRD. OR MAT. ELEV. It is of the greatest importance to have a complete history of the well. Use this form in reporting the history of ali important operations at the well, together with the dates thereof, including size of hole, size and number of bits, complete description of casing, cementing, fishing or drilling difficulties, surveys, all tests, ali completion operations and procedure, etc. DATE 1967 12/6' 12/7 12/8 12/9 12/10 12/11 12/12 PBTD 15,407' - Opened well to tank with tubing pressure decreasing from 950~ to zero immediately. Flowed 14 bbls of oil in 35 minutes with 100~ tubing pressure. Opened to tank 'for an additional 9 hours with only a very slight gas blow. Rigged up Lane-Wells and ran 2-1/8" OD sinker bars to 15,350' with no difficulty. Per- forated with 4 jets per foot 15,130-15,160'. Reperforated with 4 jets per foot 14,942-14,962", 14,994-15,009', 15 , 037-15 , 057I, 15,085-15,100', 15,160-15,185', and 15,290-15,310'. Perforating went slowly due to mechanical and fr'eezing problems. No increase in tubing pressure while perforating. Opened well to tank. Produced 9 bbls of oil and 9 bbls of water in 9 hours. No evidence of gas ~lift equipment operating. PBTD 15,407' - Rigged up and swabbed 26 bbls of Oil and 10 bbls of water from 2400'. Well flowed intermittently 22 bbls of oil and 15 bbls of water. No evidence that gas lift equipment is operating. Swabbing during daylight hours only. PBTD 15,407' - Swabbed 20 bbls of oil, 30 bbls of water and 30 bbls of mud from 4800'. Well did not flow during this 24-hour period. PBTD 15,407' - Swabbed 5 bbls of oil, 50 bbls' of water and 50 bbls of mud from 4500'. Well started flowing and flowed approximately 50 bbls of water and 50 bbls of mud in two hours, then blew wet gas for 1 hour and dry gas for 1 hour, Shut in to remove swab valve and to hookup flare line. Tubing pressure increased to 1900# in 10 minutes. Opened well to flare through s~eparator. Gas bled off in 20 minutes and started flowing mud and water. Flowed about 25 bbls of mud and water and stopped flowing. After 11 hours with no flow., made one small head of oil. Estimated recovery during this 24-hour per'iod was-10 bbls of oil, 113 bbls of water and 112 bbls of mud. PBTD 15,407' -Well flowed 28 bbls of oil in small heads of about 1/2 · bbls each while a swab and burn pit was constructed. PBTD 15,407' - Swabbed 5 bbls of oil, 13 bbls of water, and 13 bbls of mud from 4800'° Well commenced flowing and flowed mud and water for one hour. Then flowed wet gas with mud and water' for 2 hours. Then flowed 15 bbls of heavy mud in heads in one hour. Then flowed wet gas with mud and sand for one hour, gas rate estimated to be 3,000 MCF per day. Shut in well due to sand cutting of lines. Shut-in tubing pressure 2000~. Estimated recovery during 24-hour period was 5 ~ls o~ oil, 63 ~Bls o~ water and 78 bbls of mud. Total estimated recovery during 13-day test period was 237 bl~ls of .oil, 381 .bbls of water and 313 bbls of mud' D FEB ~ mc~ FORM ,~84 R£~/. 3--63, DAT[ ~ IVi ' THON OIL COMP. HIS'I uRY OF OIL OR GAS FIELD WELL NO, 2 LEASE Beaver Creek Unit PARISH STATE COUNTY. i ~ ELEV. I ToP OF OIL STRING __ ELEV. MEASUREMENTS [ToP OF ROTARY TABLE~ ELEV. TAKEN FROM L GRD. OR MATi ELEV. BLOCK SEC. TWP R. HISTORY PREPARED BY TITLE It is of the greatest importance to have a complete histOry of the well. Use this form in reporting the history of all important operations at' the well, together with the dates thereof, including size of hole, size and number of bits, complete description .of casing, cementing0 fishing or drilling difficulties, surveys, all tests, all completion operations and procedure, etc. DATE 1967 12/13- 12/16 12/17- 12/18 12/19 12/20- 12/21 PBTD 15,407' - Ran sinker bars on Lane-Wells wireline to 14,900'. On third~ arttempt set Otis blanking plug in X-nipple at 14,826'. Opened circulating valve at 14,778'. Rigged up Halliburton and pumped 400 bbls 11~ mud down tubing at 1½ bbls per minute with a maximum pressure of 2300~ and shut-in pressure of 1500~. Bled back 76 bbls of mud with tubing pressure decreasing to 575~o Pumped 90 bbls 11~ mud down tubing at 1½ bbls per minute with a maximum pressure of 23009, and a shut-in pressure of 1750~. Rigged up lubricator to set blanking plug in X-nipple at 5,518'. Otis setting tool became stuck just below or in X-nipple. While jarring, line pulled out of rope socket leaving wireline tools in hole. Total length of fish 31'. Ran collar locator and 16' of 1-3/8" sinker bars on wireline to locate fish. Tagged top of fish at 14,753' with bottom of fish at 14,784'. Wireline tool probably hung in circulating valve at 14,778'. PBTD 15,407' -Will not attempt to recover fish at this time. Rigged up new set of wireline tools and attempted to set blanking plug in X-nipple at 5518'. Could not get blanking plug and setting tool below 5,010'. Opened circulating valve at 5,115'. Pumped 53 bbls 14~ mud down tubing with a maximum pressure of 1700~ and a shut-in pressUre of 800~. Bled back 4 bbls of mud and tubing pressure decreased to zero. Installed. back pressure valve in tubing, removed X-mas tree, and installed BOP equipment. Pulled back pressure valve and tested BOP equipment and casing to 2000~, OK. Pulled packer at 5,016' loose. Unable to open packer bypass or circulate around packer. Rigged up Lane-Wells and attempted to perforate tubing at 5,006' with. Dialog tubing perforator, no penetration. Perforated from 5,000 to 5,001' with 5 shots using Dialog drill pipe perforator. PBTD 15,407' - Reversed out water in annulus above packer at 5,016' with 14~ mud. Pulled tubing string with packer, gas lift valves, circulating V'alves, etc. from hole. Both circulating valves were open. Gas lift valve and checks gone from gas lift mandrel at 5,705'. Chokes cut out on next three gas lift valves. The remaining 6 lower gas lift valves appeared to have been operating very little if .any. Did not recover wire line t0ol. PBTD 15,407' - Ran open ended tubing to 14,764'. Circulated and conditioned mud for 8½ hours. Mixed and pumped 25 sacks cement with 50 cu. ft. of water ahead of cement. Displaced cement with 10 cu. ft. of water and 535 cu. ft. of mud. Maximum pressure 2000~. Total mixing and displacement time 35 minutes Pulled up 300'. Unable to break circulation with 4000~ pressure. Pulled tubing out of hole. Laid down 34 jts '(1,030') 2-7/8" tubing with cement inside. Picked up replacement tubing and ran 0i~en__ended to 14,7~C~- ~E,~q~D~red only stringers of cement. Pulled-up to 14,770'~n~~u~a~e~ 2 hours. FFR t~ lCI~R FORM:. 484 R~£V. 3--63 Mm_, THClN OIL I:CtiVl . HIS3 JRY OF OIL OR GAS WEll FIELD WELL NO. 2 STATE MEASUREMENTS TAKEN FROM LEASE Beaver Creek Unit PARISH COUNTY. BLOCK SEC. TWP Re fToP OF Oil STRING TOP Of ROTARY TABLE GRD. OR MAT. ELEV. I ~ EIEV.. ELEV. ELEV. HISTORY PREPARED BY TITLE It is of the greatest importance to ha~e a complete history of the well. Use this form in reporting the history of all important operations at the well, together with the dates thereof, including size of hole, size and number of bits, complete description of casing, cementing, fishing or drilling difficulties, surveys, all tests, all Completion operations and procedure, etc. DATE 1967 12/22 12/23- 12/24 PBTD 15,407' -Mixed and pumped 50 sacks cement. Displaced 30 sacks out of tubing from 14,770 to 14,610'. Raised tubing to 14,410' and displaced 20 sacks out from 14,410' to 14,300'. Raised tubing to 14,110'. Unable to pump into tubing with 4000~ pressure. Waited on cement 2 hours. Tagged top of plug at 14,265' with 5000~. Pulled tubing out of hole. Found 2-7/8" tubing filled with a cement contaminated mud plug with channels throughout from 9,992 to 12,812'. Ran open ended tubing to 8700' and circulated 2 hours. Mixed and pumped 125 sacks of cement. Displaced cement out of tubing from 8700' to 8297' across liner lap. Pulled tubing out of hole. PBTD 5,290' - Rigged' up Lane-Wells, ran in and tagged top of cement plug at 8,345'. Ran 9-5/8" gauge ring to 6100'. Set 9-5/8" Halliburton cast iron bridge plug on wireline at 5644'. Could not get plug below 5650'. Perforated casing 5229 '-5244' with two jets per foot. Then perforated in error 5324-5344' due to odometer failure on wireline unit. Set 9-5/8" Halliburton cast iron bridge plug at 5290° to isolate perforations 5324-5344'. Perforated 5175-5220' with tWo jets per foot and reperforated 5155-5175' with two jets per foot. All perforations based on Lane-Wells Dual Induction log measurements. Ran 9-5/8" Guiberson RH-1 hydraulic packer on 3½" buttress tubing with packer-landed at 5073' and with bottom of tail pipe at 5112'. 3½" Tubinq Detail KB to Top Tubing Hanger 14.80' 1 CIW Tubing Hanger 0.70 160 jts 3½" OD 9.2~ N-80 Buttress Tbg 5,021.37 Otis Circulating Valve j t 3½" OD 9.2~ N-80 Buttress Tbg 3½" Buttress x 3½" EUE 8rd X..-over Guiberson RH-1 'Hydraulic Packer 3½" EUE 8rd x 3½" Buttress X-over j t 3½" OD 9.2~ N-80 Buttress Tbg Guiberson Seating Nipple . 3.78 31.28 0.95 6.80 0.80 31.22 0.78 5, I12.48 ' Om 14,80 15.50 5,036.87 5,040 o 65 5,071.93 5,072.88 5,079.68 5,080.48 14.80' - 15.50' -5,036.87 ' -5,040.65 ' -5,071.93 ' -5,072.88' -5,079.68 ' -5,080.48' -5,111.70' 5,111.70 -5,112.48' Removed BOP equipment. Installed and tested X-mas tree with 3000~, OK. Displaced mud in hole with fresh water. Set hydraulic packer with 2000~ pressure. Pumped 2 bbls of diesel into casing. Tested casing with 1000~ pressure, OK. Rigged up and made 3 swab runs to 900' recovering approximately 12 bbls of water. Well started flowing and was unloaded to pit. Shut-in tubing pressure 1700~. Flowed well for one hour at a rate of approximately 5000 MCF per day with very little water in.gas. Flowing tubing pre~C ~~'E ~lowed ~1~ ~THo~ OIL COi~P. ~Y HIS\ ~RY OF OIL OR GAS WI-~.L FIELD WELL NO., STATE BLOCK 2 LEASE Beaver Creek Un±t SEC.' TWP Roi PARISH COUNTY ~ ElEV. MEASUREMENTS ITM OF OIL STRING ~ ELEV. HISTORY PREPARED BY TOP OF ROTARY TABLE~ ELEV. TITLE TAKEN FROM LGRD. OR MATi ELEV It is of the greatest importance to have a complete history of the well. Use this form in reporting the history of ali important operations at the well, together with the dates thereof, including size of hole, size and number of bits, complete description of casing, cementing, fishing or drilling difficulties, surveys, all tests, all completion operations and procedure, etc. DATE 1967 12/25 12/26 at a rate of about 6-7000 MCF per day with a flowing tubing pressure of 1500~. Shut well in for christmas holiday. PBTD 5290' - Shut in for Christmas holiday. PBTD .5290' - Shut-in tubing pressure 1800~. Flowed well at a rate of approximately 5,000 MCF per day for 1-3/4 hours. Flowing tubing pressure stabilized at 1625~. No evidence of mud, sand or water in gas stream. Rig released at 9 AM 12/26/67. Well completed in Kenai gas ~sands 12/26/67. A 4-point open flow potential test will be conducted at a later date when'weather conditions are more favorable o RECEIVED FEB6 1968 ~'OMPLETION REPORT MARCH 27,1974 hJARATHON OIL CO. BEAVER CREEK UNIT NO. 2 KELLY BUSHING ELEVATION 158 FT. - GYRO MULTISHOT SURVEY- TANGENTIAL METHOD OF COMPUTATIONS PREPARED FOR EASTMAN-WHIPSTOCK BY F.Mo LINDSEY AND ASSOC. . . RECORD OF SURVEY ALL CALCULATIONS PERFORMED BY ! B M ELECTRONIC COMPUTER ..... TRUE MEAS. DRIFT VERTICAL DEPTH ANGLE DEPTH 0 0 0 .... 100 0 30 99,99 .. 200 0 30 199,99 _._300 0 45 299.98 __400_ 0 45 399,97 .... _._500 _0. 45 499,96 600 0 45 599,95 _700 0 30 699,95 800 0 BO 799,95 ...... 900 0 %5 899.94 SUB DRIFT DIREC DEG, 0.00 =158.00 N 23 E -58.00 N 23 E 41,99 N 35 E 141.98 N 40 E 241.97 N 52 E 341,96 N 71E 441,95 $ 50 E 541,95 S 31W 641.95 N 40 W 741.94 N 53 E __1000 0__15 999.94 841,94 S 36 W _1100 0 0 1099,94 941,94 S 0 W 1200 0 0 1199.94 1041,94 S 0 W _1300 0 0_..1299.94' 1141.94 S 0 W _1400. 0 0 ....1399,94 1241.94 S 0 W .... 1500 0 15 1499,94 1341,94 S 89 E _~600 0 15,.__ 1599,94 1441.94 S 47 W 1700 0 30 1699,94 1541,94 N 5 W __1800 0 15. 1799,94 1641.94 N 16 E TOTAL COORDINATES CLOSURES DISTANCE ANGLE D M S DOG LEG ) SEVER I TY SECTI DEG/IO.OFT DISTA 0,00 S 0,80 N 1.51 N 2.52 N 3,32 N 3.75 N 2,91 N 2.16 N 2,83 N 3,09 N 2,74 N 2,74 N 2.74 N 2,74 N 2,74 N 2.73 N 2,43 N' :3,30 N 3,72 N 0,00 W 0,34 E 0,84 E 1,68 E 2,71 E 3,95 E 4,95 E 4,50 E 3.94 E 4,29 E 4.03 E 4,03 E 4.03 E 4.03 E 4,03 E 4,47 E 4,15 E 0.00 S 0 0 0 W 0.87 N 23 0 0 E 1.73 N 28 59 59 E 3,03 N 33 43 36 E 4.29 N 39 12 43 E 5,44 N 46 28 49 E 5,74 N 59 33 38 E 4,99 N 64 20 57 E 4,85 N 54 19 20 E 5,29 N 54 12 48 E 4.87 N 55 48 53 E 4.87 N 55 48 53 E 4,87 N 55 48 53 E 4.87 N 55 48 53 E 4.87 N 55 48 53 E 5.24 N 58 33 50 E 4.81 N 59 36 17 E 4.07 E 5,24 N 50 58 2 E 4,19 E "' 5.61 N 48 24 48 E" '0.000 O. 0.500 -0, 0.105 -0. 0,256 -!~ 0.157 -2. 0,248 -3. 0,739 -4, 0,834 -4, 0.814'- -3, 0.571 -4, 0,495 0,250 0,000 -3, 0,000 -3, 0,000 "-3, 0,250 -4. O'&G4 -4, 0.683 ........... ~3. O.2B1 -4, __1900__0._15___1899,94 1741,94 N 21E ...... 4,13 N ..2000 __ 0 15 1999,94 1841.94 N 41E ....... 4,46 N _2!oo o ..... 2099.9s z941.gs s 17 E _.220~..]9'-__1% _2199,93 .... 2041,93 S 11E ..................... - . . ........ .. . 4,35 E 4,64 E 6,43 N 46 '-7 25 'E ... 4.04 N . 4.76 E 6.25 N 49 '~X-33 E ._. 3,61 N 4,85 E 6,05 N 53 17'-53'-E · .. 6.00 N 46 29 44 E'" 0.022 .......... -4. 0-087 -4'. 0.437 -4, 0.026 ' -4, , .... RECORD OF SURVEY .................. ALL CALCULATIONS PERFORMED BY I B M ELECTRONIC COMPUTER . TRUE MEAS. DRIFT VERTICAL DEPTH ANGLE DEPTH . _ SUB DRIFT SEA DIREC DEG. TOTAL 'COORDINATES _2300 0 15 2299,93 2141o93 S 26 E .2400 0 15 2399,93 2241,93 S 51E ._.2500. 0 15 2499,93 2341.93 N 77 W _~2600 _0 0 2599,93 2441.93 N 0 W __2700 0 0 2699,93 2541,93 N 0 W _..2800 .0_15 2799,93 26#1,93 S ll W _2900 _0 15 2899,93 2741,93 N 80 W ...... 3000 0 0 2999.93 2841,93 N 0 W _3100 0 0 3099,93 2941,93 N 0 W 3.22 N 2.94 N 3,04 N 3.04 N 3.04 N 2.61N 2,69 hi 2.69 N 2,69 N --3200 0 15 3199,93 3041,93 N 58 E ............. 2,92 N _3300 0 15 3299,93 3141.93 N 42 E .... 3400 0 15 3399,93 3241.93 'S 34 E _.3500 0 30 3499,92 3341,92 S 80 w _3600 0 15 3599,92 3441,92 N 30 E _ 3700 0 15. 3699,92 3541,92 N 16 E ._.3800 0 0 .... 3799.92 3641,92 N 0 E _3900 0 15 3899,92 3741.92 S 35 W _.4000 0 15 3999.92 3841.92 S 58 W _4i00. 0 3O ...... 4099.91 3941,91 Al 15 E 3,25 N 2,88 N 2.73 N 3.11 N 3.53 N 3.53 N 3,17 N 2.94 N 3,78 N 5.04 E 5.38 E 4.95 E 4.95 E 4,95 E 4,87 E 4.44 E 4.44 E 4.44 E 4,81 E 5.10 E 5,34 E 4.49 E 4.70 E 4,82 E 4.82 E 4,57 E 4,20 E 4.43 E __4200, 0 15 4199.91 ..4041.91 S 35 W .... 4300 0 30_ 4299.9I 4141.91 S 45 W --4400_._0.30 ...... 4399,91 ...4241,91 S 43 W _4500 0 30 4499.90 4341.90 S 55 W _4600 ..... 0 30 4599,90 4441,90 S 36 W -- _4700 ..... 0 45 .... 4699,89 4541,89 ...S 25 W 3,43 N ' 4,18 E 2,81 N 3,56 E 2.17 N'__.~..~ ...... 2.97 E 1,67 N 0,96 N 0~21 S _4800 .... I.._0 4799,87 4641,87. S ..... 5 W .......... 'i,95 S 4900 ...! .... 0 ._4899,86 4741',86. S. 3 W 3,69 S DOG LEG C L 0 S U R E S SEVERITY SECTIC DISTANGE ..... ANGLE DEG/IOOFT DISTAh ~,. D M S 2,25 E .. . 1,74 E 1,19 E 1,03 E 5.98 N 57 24 21 E 6.13 N 61 16 27 E 5.81 N 58 24 48 E 5.81 N 58 24 48 E 5.81 N 58 24 48 E 5.53 N 61 44 32 E 5.19 N 58 45 43 E 5,19 N 58 45 43 E 5.19 N 58 45 4'3 E 5,63 N 58 42 11E 6.05 N 57 30 57 E 6.07 N 61 37 48 E 5,25 N 58 37 56 E 5,64 N 56 30 35 E 5.98 N 53 47 41 E 5.98 N 53 47 41 E 5.57 N 55 14 25 E , 5.13 N 55 0 21 E 5,83 N 49 29 10 E 5.41 N 50"38 31 E · 4,54 N 51 43 27 E 0.065 0.108 -5.2 0.487 -4.] . 0.250 -4,i -. 0.000 -4,7 . .... 0.250 -4,7 ... 0.350 0.250 -4,2 0.000 -4.3 -. 0.25'0 -4,6 Il 0.070 -4.S 0.394 -5,] 0,644 -4.3 0-688 --4,5 0,061 --4,6 _. 0,250 0.250 ,4 ._ · _. '0.I00 -4,C 0.704 -4.2 0.740 -4.C 0.257 -3,4 -2.8 3.68 N 53 47 1 E 0.017 2.81N 53 24 22 E O.iC5 -2.1 1.99 N 60 55 26 E :0~165 -1.6 1.21 S 79 41 1 E 0.276 -1.1 2.21 S 27 58 22 E 0,391 ' .. -1,1 ........ 0,94 E 3,81 S 14 21 54 E 0.035 ~"1.1 _5.0.00. __! _30___.,A999,82 _4841,82 S _.. 7..,E ............. 6'29,_S '.., .-ii'1,.26 E ..... .i',i. 6,42 S '11 '22 12 E ....... 0.544 ............ -1,5 --5100 . .1 15 .... 5099,80 -4941,80 ...... S.. B .E 8,47 S ........ 1,38..E ............ 8~58 S___9 15.__ 2 E_. 0,268 .............. --.1,8 · RECORD OF SURVEY ' '' ALL. CALCULATIONS PERFORMED BY .... I B.M ELECTRONIC CONPUTER ~,. _. __ TRUE MEAS, DR-IFT VERTICAL D EP_TH ANGLE ...... DEPTH ........... tD Iq .. SUB DRIFT SEA DIREC DEG, TOTAL COORDINATES . .. ~i~5200. 1 15 5199,78 5041.78 S 22 E 5300 1 0... 5299,76 5141,76 FI 84 E _5400 ! 0 539'9,75 524!,75 N 52 E _5500 .... ! 0_. 5499.73 5341.73 N 32 E __5600 __0 30 5599,73 5441o73 N 14 E _5700 ...... 0 45 .....5699°72 5541,72 N 8 W _. __._580~ .....0 30 .....5799,72 5641,72 N 46 W ~~ _5900 O 30 ..5899,71 5741,71 N 51W __6000 0 15_. 5999,7! 5841,71 N 65 W __6100 .... 0 15 _.6099,71 5941,71 S 40 W __6200 0 0 ....6199,7I 6041,71 S 0 W _6300 0 0 6299,71 6141,71 S 0 W _6400.. 0 0 ..... 6399,71 6241.71 S 0 W _..6500 0 15 6499,71 6341.71 N 22 E _6600 0 0 6599,71 644.1,71 N 0 E _6700 0 0 _..6699,71 6541,71 N 0 E --- CLOsUREs '- DISTANCE ANGLE D N S . . _6800. _ 0 15 6799.71 6641,71 S 25 E ....... 4,60 _6900 0 0 6899,71 6741.71 S 0 E 4.60 _7000_._0 15 ....... 6999,71 6841,71 S 84 E .... 4,64 _7100 0 15 7099.71 6941.71 N 80 E ...... 4,57 __7200 0 45 7199.70 7041,70 N 85 E'" 4,45 _7300 1 0 7299,68 71~1,68 S 85 E --' 10,31S 3.93 E 9,24 S 5.30 E 7,76 S 6,23 6.91 $ 6.44 E ., 5,61 $ 6,26 E 5,01 S 5,63 E 4,46 S 4,95 E . 4,27 S 4,56 E 4.61 5 ~.28 E 4.61 S 4.28 E __ 4,6! S 4.28 E ... 4,61 $ 4,28 E 4,20 S 4.44 E 4,20 S 4,44 E 4,20 S 4,44 E . - 4.62 E 4,62 E 5,O6 E . 5,49 E 6,79 E 4,6! S ' 8,53 E _7400 1 15 7399.66 7241.66 S 57 E .......... 5.79 S ........ 10,36 E 7500._ .1 15 7499,63 7341.63 S 50 E .... 7,20 S '12,03 E --7600_.. 0.~5~17599,63 ... 7441,63 S 36 E ............ 8.26 S 12,80 E __7700_.0 15 .... 7699,62 7541,62 S 21E , 8,66 S _.7800 0 t5 7799.62 7641,62 S 1W 9,10 S __79D~'-~_0__0__.7899.62 7741,62 S 0 W ..... 9,10 S 10.72 S 11 49 24 E 11,03 S 20 52 19 E 10,65 S 29 52 34 E 9.95 S 38 46 17 E 9,45 S 42 59 15 E 8.41S 48 6 22 E 7.54 S" 48 20 59 E 6,66 S 48 0 11 E 6,25 S 4650 3 E 6,29 S 42 51 51 E 6,29 S 42 51 51 E 6,29 S 42 51 51 E 6,29 S 42 51 51 E 6.11 5'46"33 54 E 6,11 S 46 33 54 E 6.11 S 46 33 54 E 6,52 S 45 925 E 6,52 S 45 925 E 6,87 S 47 26 21 E 7.14 S 50 '13 4 E 8,12 S 56 43 53 E 9.70 S 61 37 10 E 11,87 S 60 46 18 E 14,02 S 59 6 21 E 15,23 S 57 10 27 E 12.96 E 15,59 S 56 13 39 E 12.95 E 15.83 S 54 53 '59 E 12~95' E .... 15.83 S 54 53 59'"E DOG LEG SEVER I TY SECTIO DEG/IOOFT DISTAN 0,413 - 7 . 1,369 -4,4 0.551 -5,7 0.347 -6.6. 0,547 -6,7 0,~42 -6,5 0.471 -5,8 0,044 -5.1 0.264 -4,7 0,304 -4.5 0.250 -4,5 0.000 -4,5 0,000 -4,5 0,250 -~.6 -- . 0.250 -4,6 0,2500'000 ->i6. 0,250 - 8 0,250 -5,2 0,070 ....... ~5.7 0,50! -7.0 0,292 ....... -8,7 0,596 -10,6 0,153 ....... -12,3 0.553 -13.2 0.513 -13.3 . . 0,095 -l~, 3 0.250 -13.3 8000..0 0.__7999.62 __7841.62 S O...w. ............... 9_..10_S -~i'i 12..._95._._E_"_-~.~ .... . 15.83 S._5Z~-53 59 E ..... o.o00 ..... -13.3 ....... RECORD OF SURVEY ................. ALL CALCULATIONS PERFORMED BY ! B M ELECTRONIC COMPUTER ,,.' TRUE MEAS, DRIFT VERTICAL SUB D EP_.T H ANGLE DEPTH SEA D M _.. DRIFT DIREC DEG, TOTAL COORDINATES CLOSURES DISTANCE ANGLE D M S DOG LEG SEVERITY SECTI( DEG/IOOFT DISTA> . . _8100 0 30 8099,62 7941,62 S 35 W 8200 0 30 8199.62 8041.62 S 23 W 8300 0 15 8299.62 8141,62 S 12 W _~400 0 30 8399,61 B241,61 S 22 W _8500 0 45 ._ 8499.60 8341,60 S 11 W ..... 8600 1 0 8599,59 8441,59 S 5 W _8700_._ 1 15 .....8699,56 8541,56 S 1W _8800 1 0 8799,55 8641,55 S 2 W ....... 8900 0 45 8899,54 8741,54 S 1E ___9000.. 1 ..0 8999,52 8841,52 S 0 E _..9100. 1 0 9099,51 8941,51 S 8 E 9200 1 0 9199,49 9041,49 S 8 E _9300...1 ..... 0 .9299,48 _9141,48 S 8 E .... 9400 1 0 9399,46 9241,46 S 16 E _)500 1 0 9499.45 9341,45 S 12 E _9600 .... 0__.45 9599,44 9441,44 S 5 E ..... 9700 1 0 9699,42 9541,42 S 3 E _9800 0 BO 9799,42 9641,42 S 8 W ._9900 0 30 .... 9899.42 9741,42 S 20 10000 ._0 30. 9999,41 9841,41 .!0!00 0 15 10099,41 9941,41 $ 58 W 10200 ..... 0 30._10199,41 10041,41 S 9,81 S 10.62 1!,04 S 11,85 S 13,14 S 14.88 S 17.06 S 18,80 S 20,11 S 21,86 S 23,58 S 25,31 27,04 S 28.72 S 30,43 S 31,73'5 33,47 $ 34,34 S 35,I6 S 35,92 S 36,15 S B6,87 S' ..!.0300 .. 0 30 10299,40 10141,40 S 24W ~0.400... 0._.15 10399,40 10241,40 S 27 E .10500 .... 0_.!5..,10499,40 10341,40 $ 26 W 20600 .0 0 10599,~0 10441,40 S 0 W 10700 0 0.. 10699,40 10541,40 S 0 W ~.P8~9~]'~ .... 0..lp799.40 10641,40 S '0 W 10900___.0 15,10899,40 10741,40 N .... 37,67 S 38,06 S' 38,45 S 38,45 S 38.45 S 12.45 E 12.11 E 12.02 E 11,69 E 11,44 E 11,29 E 11,25 E ll.i9 E 11,21 E ll.21 11.45 E 11.70 11,94 E 12.42 E 12,78 E 12.90 E 12e99 E 12,87 12.57 E 12,15 E 11,78 E 11.29'5 10,93 E 11.13 E 15,85 S 51 44 43 E 16,10 S 48 44 58 E 16,32 S 47 24 49 E 16.65 S 44 36 7 E 17.42 S 41 2 55 E 18.68 S 37 11 31 E 20,,43 S 33 24 30 E 21,88 S 30 45 36 E 23,03 S 29 8 37 'E 24.57 S 27 9 40 E 26.22 S 25 54 34 E 2?.89 S 24 48 25 E 29,56 S 23 49 44 E 31,29 S 23 23 37 E 33.00 $ 22 /+7 4'3 E 34,.25 S 22 7 34 E 35,91 S 21 12 49 E 36-67 S 20 32 54 E 37,34 S 19 40 40 E 37.92 S 18 41 15 E 38,02 S 18 2 52 E 38,56 S 17 1 32 E 39.23 S'16 II 20'E 39,66 S 16 18 26 E 0 · 500 - 0,105 -12.6 0.259 -12. 0.257 -12.1 0,276 -12,C . _ 0,266 -12.{ 0.262 -12.] 0.251 -12.] 0.254 -12.[ 0,250 -12.2 0,1/+0 0,000 -I2. c. 0.000 -13.~ 0-140 -13.E 0,070 --14e2 0,271 -~,~ 0,252 ' 0,513 -14,5 0,105 -14,2 0,078 0-306 " -13.5 0,290 -13.] 0-087 -12,E 0,394 -13.C 10,94 E _. 39.98 S 15 53 11 E 0,223 -12.E 10,94 E 39,98 S 15 53. ll'E .... 0.250 .......... -12.~ 10,94 E ._ 39,98 S .15 53 ll E ' lo 794_ ¢ ....... 39.98 s ........ =:,;q ........................................................................................... ' ......' -. RECORD OF SURVEY ALL ._CALCULATIONS PERFORMED BY I B M ELECTRONIC COMPUTER : , · TRUE MEAS. DRIFT VERTICAL DEPTH ANGLE DEPTH D M SUB DRIFT SEA DIREC DEG. TOTAL COORDINATES C L 0 S U R E S DISTANCE ANGLE D M S DOG LEG SEVERITY SECTIC DEG/IOOFT DISTA~ 1!000 0 30 10999.40 10841.40 N 15 W ii100 0 45 11099.39 1094!.39 N 12 W 11200 I 0 11199.37 11041.37 N 0 W 11300 ! 0 11299.36 11141,36 N 4 W 11400_. 0 45 11399,35 11241,35 N 9 W 11500 0 30 11499.35 11341.35 N 18 W 11600 0 30 11599,34 11441,34 N 8 W - 11700 0 15 11699,34 11541,34 N 20 W 11800 0 15 11799,34 11641,34 N 7 W ~.1900 _~_0 0 11899,34 11741,34 N 0 W ~.2000 0 0 11999,34 11841,34--N 0 W .... 12100 0 0 12099,34 11941,34 N 0 W 12200 0 30 12199.34 12041,34 N 41W ~'i2300 .... 1 0 12299.32 12141,32 N 40 W 12400 1 0 12399.31 12241,31 N 40 W 12500._ ! _.0 12499,29 12341,29 N 42 W 12600 1 0 12599,28 12441,28 N 43 W 12700 1 15 12699,25 12541,25 N 44 W 12800 ! 15 12799.23 12641,23 N 46 W ' 12900 1 0 !2899,21 12741.21 N 44 W 13000 _. 0 45 12999.20 12841,20 N 46 W _~3100 0 30 13099,20 12941,20 N 43 W 13200 0 45 13199.19 13041.19 N 44'W 13300 0 45 13299,18 13141,18 N 43 W-- 13400 .... 1 01!3399,17 13241.17 N 44 W 37,17 S 10,75 E 35,89 S 10,48 E 34,15 S 10,48 E 32.41 S 10,36 E 31,12 S 10~15 E 30,29 $ 9,88 E 29.42 S 9,76 E 29,01 S 9.61 E 28,58 S 9.56 E 28,58 S 9.56 E 28,58 $ 9,56 E 28,58 S 9,56 E · 27,92 S 8,99 E 26,58 S 7,87 E 25,25 S 6,74 E 23,95 'S 5.58 E · . . 22,67 S 4,39 E 21,10 S 2,87 E 19.59 S 1,30 E 18,33 S 0,09 E 17,42 S 0.84' W i6,78 S' 15,84 S ...... 14,89 S 13,63 S _- 13500 1 O. 13499.15 13341,15 N 46 W ......... 12,42 13600 ._1 15 13599.13 13441,13 N 49 W- "10.99 1~300 _1 .... 0 13699,11...13541,11 N 51 W ........ 9,89 _!3800 1 ..... 0..1579.9.10 13641,10 . N.5!._W ................8,..7_~._.S 38.70 S 16 8 12 E 0.279 37.39 S 16 16 53 E 0.252 35,72 S !7 3 58 E 0,309 34,02 S 17 43 49 E 0,070 32,73 S 18 4 41 E 0,261 31.86 S 18 4 49 E .... 0.268 31,00 S 18 21 45 E 30.56 S 18 20 21 E 0-261 30,14 S 18 30 8 E 0,057 30,14 S 18 30 8 E "'0,250 30.14 5 18 30 8 E 0.000 30.14 5 18 30 8 E 0.000 29.33 $ 17 51 0 E 0,500 27.72 S 16 29 25 E ........0.500 26,13 S 14 57 50 E 0,000 24,59 S 13 6 56 E 23.09 S 10 57 29 E 21,30 S 7 45 26 E 19,63 S 3 48 51E 18.33 S -0"17 35 E 17,44 S 2 47 5 W -12.; -12,] -11,5 -11,7 · . -11," 0,087 ............. -11,~ -ll,C -10.5 -!0,~ -10,~ - -'10.~ -10.2 0.035 0,017 0,2.51 -3,5 0.044 -2.2 0,253 -1,¢ 0,252 -0.£ 1.44 W 16.85 S 4 54 42 W .... 0,252 2,35 'W ..........16,02 S 3,2.4 W 15,24 S 12 17 35 W 4,45 W ......... 14,34 S 18 6 6 W .... 0.250 5,71W 13.67 ...... _ 7,35 W 13,22 S 33 48 8 W O ....... 8,71 ~ .......... 13,18 10,.07_.~ ............ 13,37 S ~8 52 INTERPOLATED TRUE CODE MEASURED _ _ NA?,IE DEPTH VER T I CAL TRUE VERTICAL DEPTH DEPTHS, COORDINATES AND CLOSURES FOR GIVEN DEPTHS TOTAL COORDINATES CLOSURE DISTANCE ANGLE D M SUB SEA SAND SAND SAND SAND SAND SAND SAND SAND SAND SAND SAND SAND SAND 5136 5152 5220 5230 5310 6000 8130 8600 9930 12025 14334 14679 14837 5135.79 5151.79 5219,77 5229.77 5309.76 5999,71 8129~62 8599.59 9929,42 12024°34 14333.01 14677,99 14835.97 9.20 9,52 10,46 10,44' 10.20 4,27 10.05 14,88 35,39 28.58 2,88 0.49 0,71 1.67 E 1.80 E 2,54 E 2,71 E 4,07 E 4.56 E 12.35 E 11,29 E 12.44 E 9.56 E 17,63 W 20.93 W 22.61 9,35 S 10 18 44 E 9,69 S 10 43 48 E 10,76 S 13 40 18 E 10.79 S 14 55 24 E 10,98 S 21 44 30 E 6.25 S 46 50 3 E 15,92 S 50 50 12 E 18.68 S 37 11 31 E 37,51 S 19 22 39 E 30.14 S 18 30 8 E 17.87 S 80 43 9 W 20.94 S 88 39 1W 22.62 N 88 10 35 W 4977.79 4993.79 5061,77 5071.77' 5151.76 5841,71 7971.62 8441,59 9771,42 11866.34 14175.01 14519,99 14677,97 RECORD Of ALL CALCULATIONS PERFORMED BY _ TRUE MEAS, DRIFT VERTICAL DERTH ANGLE DEPTH D M SUB SEA DRIFT DIREC DEG, i'3900 1 0 13899.08 13741.08 14000 ! 0 13999.07 13841.07 14100 1 0 14099.05 13941.05 1.4200 1 15 14199,03 14041,03 14300 1 0 !4299,01 14141,01 .~4400_ 0 45_14399,01 14241,01 1~500_. 0 30_14499,00 14341,00 14600.. 0 45 14598,99 14440,99 14700 0 45 14698,98 14540,98 J~_8.00 ......0 45 14798,98 14640,98 1.AGO0 0 45 14898~97 14740,97 .. SURVEY B M ELECTRONIC.COMPUTER ., TOTAL HOLE CLOSURE 23.32 ._ N 53 W 7.74 N 54 W 6.71 N 49 W 5.57 _ N 52 W 4.23 N 52 W 3,15 N 52 W 2.35 N 54 W 1.83 N 58 W 1,14 N 51 W 0.32 N 54 W 0,44 N 56 W 1.18 ,.. COORDINATES _. FEET AT N 87 5 52 W S 11.46 W S 12.87 W S 14.19 W S 15.91 W S 17,28 W S 18.32 W S 19,02 W S '20. I3 W S 21,15 W N 22,21 W N 23.29 W ._ - CLOSURES DISTANCE ANGLE D M DOG LEG SEVERITY DEG/IOOFT 13.83 S 55 57 40 W 0.035 14.52 S 62 26 44 W 0.017 15.24 S 68 33 38 W 0.087 16.46 S 75 6 39 W 0.257 17.57 S 79 39 11W 0.250 18.47 S 82 41 18 W 0.250 19.11 S 84 28 59 W 0e251 20.16 S 86 44 53 W 0.254 21.15 S 89 7 57 W 0.092 22.21 N 88 50 30 W '0.099 23.32 N 87 5 52 W 0.026 SECTIO DISTAN .._ 12.5 13.8 15.6 . _ 17.1 18.1 18.9 20,0 21.1 22.2 23.3 Form 9-331 (5ia.~1963 ) 'ITED STATES su~ (Other instructlc ~ o~ re- DEPARTMr_NT OF THE INTERIOR vets, side) GEOLOGICAL SURVEY SUNDRY NOTICES AND REPORTS ON WELLS (Do not use this form for propo.~als to drill or to deepen or plug back to a dlfllerent reservoir. Use "APPLICATION FOR PERMIT--" for such proposals.) Form approved. Budget Bureau No. 42--R14~t. 5. LEASE DESIGNATION AND SERIAL NO. A-028118 6. IF INDIAN, ALLOTTEE OR TRIBE NAME UNIT AGREEMENT NAME Beaver Creek Unit WELL WELL i .OTHER 2. NAME OF OPERATOR 8. FARM OR LEASE NAME Marathon Oil Company (Operator) Beaver Creek Unit 3. ADDRESS OF OPERATOR 9. WELL NO. P, O. Boxy: 2380, Anchorage, Alaska 99501 2 - 4. LOCATION OF WELL (Report location clearly and in accordance with any State requirements.* See also space 17 below.) : At surface 590' south and 1979' west of NE corner of Sec 3,16N, RIOW, S.M. 14. PERMIT NO. J15. EI,~VATIONJ~ (Show whether OF, ~r, aR, eto.) 140.3 GR 10. FIELD AND POOL~ OR WILDCAT 'Wildcat 11, SEC,, T., R., M,, OR BLK, AND '.' SURVEY OR AREA . Sec 3 T6N RIOW SM 12. COUNT~ OR P~IS~I 13. STATE Kenai . ,.,,..J Alaska 16. Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data ':- NOTICE OF INTENTION TO: TEST WATER SHUT-OF~ ~ PULL OR ALTER CASING FRACTURE TREAT .MULTIPLE COMPLETE SHOOT OR ACIDIZE ABANDONS REPAIR WELL CHANGE PLANS (Other) .- SUBSEQUENT REPORT OF-' ..' FRACTURE TREATMENT ALTERING CASINO . . . SHOOTING ~X~I~ .. ABANDONMENT* (Other) NOTE: Report results of multiple completion on' Well ompletion or Recompletlon Report and Log form.) 17. DESCRIBE PROPOSED OR COMPLETED OPERATIONS (Clearly state all pertinent details, and give pertinent dates, including estimated date of starting any proposed work. If well: is directionally drilled, give subsm'face locations and measured and true vertical depths for all markers and zones perti- nent to this work.) * . After abandoning the Hemlock, the well was completed in the Kenai Gas Sands as follows· 12/23 Perforated casing 5229-5244' with 2 jets/ft. Then perforated in 'error 5324-5344' due to odometer failure on wireline unit. Set 9-5/8" Halliburton cast iron bridge plug at 5290' to isolate perforations at 5324-5344' Perforated 5175-5220.' with 2jets/ft. Reperforated 5155-5175' with 2 jets/ft. Ali perforations based on Lane-Wells DIL measurements. Ran 9-6/8" Guiberson RH-1 packer on 3-1/2" OD: 9.2#' N-80 buttress tubing. Landed packer at 5073' with bottom of tail pipe at 5112',. 12/24 Removed BOPE. Installed and tested xmas tree with 30004/ - OK..,. O~splaced mud 'in hole with fresh water. Set packer with 2000# pressure. Pumped'2 bbl diesel into casing. Tested casing with 1000# - OK. Made 3 swab runs to 900' and well started flowing. Unloaded well to pit. Shut in tubing pressure 1700#. Flowed Wel'l..ifor 1 hr at an approximate rate of 5000 MCF/D with very little water in gas. ~'.Fl.owing tubing ~pressure 1600#. Flowed a.t a rate of about 6-7000 MCF/D with a flowing ~tubi.n.g pres?ure.of 1500#. Shut well in for Christmas holiday. 12/26 Shut in tubing pressure 1800//. Flowed well at an approximate rate:of ]5000. 'McF/D for 1-3/4 hrs. Flowing tubing pressure stabilized at 1625#. No evidence 'of mud,[water, or sand in gas stream Rig released 9 a m. 12/26/67 · · · ; ~- .~ .:, - , Well completed in Kenai Gas Sands 12/26/67. A 4-point Open Flow Poteni;ial:[Test will be conducted at a later date when weather conditions are more favorables,? 18, I hereby certify thaL~h~ foregoing is true and correct · ,./~/,:~,.. ~; I-: - :.,,.. .:..~. ...... T~T.,...,Advanced Pet. roi,urn Engi0'eer..',:~j,.~: 1/4/~8 .. ,.. (This space for Federal or State~ o~ce use) CONDITIONS OF APPROVAL, ~ ANY: D *See IntruSions on. Revere Side , j ~ DIVISION O~ ~INES ANCHO~GB Form 9-331 (May 1963) ;'~ iTED 'STATES systat (Other iustrue on DFPARTi,._NT OF THE INTERIOR verse side) GEOLOGICAL SURVEY SUNDRY NOTICES AND REPORTS ON WELLS (Do not use this form for proposals to drill or to deepen or plug back to a different reservoir. Use "APPLICATION FOR PERMIT--" for such proposals.) I~'orm approved. Budget Bureau No. 42-R1-~24. LEASE DESIGNATION AND SERIAL NO. A-028118 6. IF INDIAN, ALLOTTEE OR TRIBE NAME I. 7. UNIT AGREEMENT NAME OIL ~ (}AS WELL WELL ~i OT.ER Beaver Creek Unit 2. NAME OF OPERATOR Marathon 0il: Company (Operator) 3. ADDRESS OF OPERATOR 'P 0 Box 2380, Anchoraqe, Alaska 9950-1 4. LOCATION OF WELL (Report location clearly and in accordance with any Sta~ requirement.* See also space 17 below.): At su~ace : 590' south and 1979' west of NE corner of sec 3, T6N, RIOW, SM J1§. ELEYATIONS (Show whether DF, ET, Ga, etc.) 140.3 GR 14. PERMI~ NO. 8. FARM OR LEASE NAME Beaver Creek' Unit 9. WELL NO. . 2 10. FIELD AND POOL~ OR WILDCAT Wildcat I~EC,~ T., R.~ M., OR BLK. AND SURVEY OR ~EA Sec 3 T6N R10W SM !2, ~OUNT, o,,.:a ~,~ISaI la. STATE Kenai -' ":'l Alaska 16. :iCheclc Appropriate Box To Indicate Nature of Notice, Report~ or Other Data NOTICE OF INTENTION TO: TEST WATER SHUT-OFF [ I PULL OR ALTER CASINO FRACTURE TREAT M ~IULTIPLE COMPLETE SHOOT OR ACIDIZE ABANDON* REPAIR WELL CHANGE PLANS (Other) SUESE~ENTf'a~OaT O~: WATER SHU~-OFF ~ -,':' '" ~ REPAIRING WELL FRACTURE TREATMENT ALTERING CASING SHOOTING OR ACIDIZING ABANDONMENT$ (Other) Hem! o¢ ~ NOTE: Report results of multiple completion on Well ompletion or Recompletion Report and Log form.) 12/17- 12/18. 12/19 12/20- 12/21 17. DESCRIBE PROPOSED OR COMPLETED OPERATIONS (Clearly state all pertinent details, and give pertinent dates, including estimated date of starting any proposed work. If well is directionally gtrilled, give subsurface locations and measured and true vertical depths for all markers and zones pertl- nent to this work.) * The Hemlock Zone was deemed sub-commercial after a 13-day test period during which 237 bbl oil, 381 bbl water, and 313 bbl mud were recovered. The Hemlock Zone was abandoned as follows: 12/15- Set Otis blanking plug in X-nipple at 14826' and Opened circulating valVe at 14778'.. 12/16 Pumped 414 bbl :11# mud down tubing to kill well. Attempted to set blanking, plug in X- nipple at 5518'". . : Lost wireline tools when setting tool stuck below or inlX-nipple Ran collar locator and tagged top of fish at 14753'. Opened circulating valve at 5115' Pumped 53 bbl 14# mud doWn, tubing. Removed xmas tree and installed BOPE. Pull'ed ;acker at 5015' loose. Could not circulate, around packer. Perforated tubing at 5000-5001' with 5 shots. Reversed out water in annulus above packer with 14# mud. Pulled'tubing 'wit'h ]ewelry out of hole. Did not recover wireline tools. Ran open ended.tubing to 14764'. Circulated and conditioned mud forl 8-1/2 hrs. Mixed and pumped 25 sx cement with 50 cu ft'water ahead of cement. Pulled up 300'. Unable to break ci. rculation with 4000# pressure. Pulled tubing out of hole.,' /Laid down~1030' 2-7/8" tubing with cement inside. Ran open ended tubing to 14790,~encountering only stringers of cement. Pulled up to 14770' and circulated 2 hrs.' --. 12/22 Mixed and pumped 50 sx cement. Displaced 30 sx out of tubing fromi14770-14610' Raised tubing to 14410' and displaced 20 sx from 14410-14300'..Waited.on-cement 2 'hrs] Tagged top of plug with '5000# at 14265'. Ran open ended tubing to 8700.',.~ ::Displaced 125 sx out of tubing from 8700-8297' across liner lap. Pulled continued : 18. I hereby certify tl~at ~hejfo~going is true and correct -. -' '~ · ,.: .- ~; .Z~' / : ..... ,,,' ,~-,-~., / Advanced Petroleum Engineer ~ 4 68 /' / , '- . ., (This space for Federal Or State office use) APPROVED B~ ~I~ *See Instru~ions on Revere Side DIVISION OF MINES & MINERAL~ ANCHORAGE Form 9-331 (May 1963) " ~"!]TED STATES SuB~IT ZN (Other lnstruc , o~ DEPART::v,~NT OF THE INTERIOR GEOLOGICAL SURVEY SUNDRY NOTICES AND REPORTS ON WELLS ~Do not use this form for proposals to drill or to deepen or plug back to a different reservoir. Use "APPLICATION FOR PERMIT--" for such proposals,) : Form approved. Budget Bureau No. 42-R1,,24. 5. LEASE DESIGNATION AND SERIAL NO. A-028118 6. IF INDIAN, ALLOTTEE OR TRIBE NAME 1. , 7. UNIT AOREEMENT NAME WELL WEL~ OTHER Beaver Creek Unit 2. NAME OF OPERATOR Marathon 0il Company (Operator) 3. ADDRESS OF OPERATOR P 0 Box 2380, Anchorage, Alaska 99501 LOCATION OF WELL (Report location clearly and in accordance with any State requirements.* See also space 17 below.) At surface 590' south and 1979' west of NE corner of Sec 3, T6N, RIOW, SM FARM OR LEASE NAME Beaver Creek Unit 9. WELL NO. 2 10. FIELD AND P00L~ OR WILDCAT Wildcat SEC., T., R., M,, OR BLi~. AND SURVEY OR ~JBA Sec 3 T6N R10W SM 14. rER,~iIT NO. i I15' EL~v*~IoNS (Sh°WwhetherDr'"T'°E'et~)140.3 GR ~. COUNTY OR,,~ISHJ XO. STAT,.. Kenai ' Alaska z6. ~Check Appropriate Box To Indicate Nature of Notice, Repoff, or Other Data NOTICE OF INTENTION TO: TEST WATER SHUT-OFF I [ PULL OR ALTER CASING FRACTURE TREAT MULTIPLE COMPLETE SHOOT OR ACIDIZE ABANDONs REPAIR WELL CHANGE PLANS (Other) SUBSEQUENT REPORT OF ~ WATER sHUT-oFF . . REPAIRING WELL FRACTURE TREATMENT ALTERING CASING SHOOTING OR ACIDIZING AEANDONMENTs (Other) Hem! ock , NOTE: Report results of multiple comp]etlon on Wen ompletion or Recompletion Report and Log form.) 12/23 Another Sundry Notice:will 17. DESCRInF, rROPOSEO OR COMPLETED OPERATIONS (Clearly state all pertinent details, and give pertinent dates, including estimated date of starting any proposed work. If well is direct,anally .drilled, give subsurface locations 'and measured and true vertical depths for all markers and zones perti- nent to this work.) * .~: ..._. '. ' .'~ Page 2 Ran in and tagged top of cement plug at 8345' with wireline.-: 6100' Set 9-5/8" Halliburton cast iron bridge plug at 5644!. plug ~elow 5650'.. HEMLOCK ABANDONED on 12/23/67. be submitted for the completion of this ~eli:] :in"the:!Kenai ~.Ga$ Sands. Ra:n 9:5/8'r gauge r. ing to -Could not_get br:.~.dge' 18. I hereby certify that :the[fo~regoin~ is true and correct SIGNED -'-'" ~iTL~.Advanced Petroleum Engineer' '~E 1/4/68 (This space for Federal~0r Stat~ Grace use) APPROVED BY'../,/~¢ CONDITIONS OF APPROVAL, IF ~: *See Instructions on Reverse Side DIVISION OF MINES & MINERALS ANCHORAGE Form 9-331 (May 1963) x'~! ITED 'STATES (Other instruc. ~ on r~ DEPARTN~NT OF THE INTERIOR GEOLOGICAL SURVEY SUNDRY NOTICES AND REPORTS ON WELLS (Do not use this form for proposals to drill or to deepen or plug back to a different reservoir. Use "APPLICATION FOR PERMIT--" for such proposals,) - OIL [_] GAS [] WELL WELL OTHER 2. NAME OF OPERATOR Marathon Oil Company ADDRESS OF OPERATOR P. O. Box 2380 (Operator) LOCATION OF WELL (Report location clearly and in accordance with any State requirements.* See also space 17 below.)i~ At surface 590' south and 1,979' west of NE corner of Sec 3, T6N, RIOW, S.M. 14. PERMIT NO. 15. EI~-VATIONS (Show whether DF, RT. OR, e~.) 140.3' GR Budget Bureau No. 5. L~ASEA_028DESIONATIONl 18 AND SERIAL NO, {~, IF INDIAN, ALLOTTEE OR TRIB~ NAME UNIT AOREEMENT NAME Beaver Creek Unit 8. FARM OR LEASE NAME Beaver Creek Unit 9. WELL NO. 2 10,' FIELD AND POOL, OR WILDCAT ' - Wi ldcat 11.' BEC., T., R., M., OR BLK. AND SURVEY OR AREA - ._ ~" 'Sec 3' T6N RI OW SM 12. COU~TT os F~ISHI 13. STATE ~!~ Kenai ~I'~ Alaska · 16. '(he~l~ Appropriate Box To Indicate Nature of Notice, Report, or ot~er Data NOTICE OF INTENTION TO: TEST WATER SHUT-OFF t~l PULL OR ALTER CASING FRACTURE TREAT [__~.[ MULTIPLE COMPLETE SHOOT ~~ ABANDON* i .... ',;~ REPAIR WELL CHANOE PLAN8 (Other) SUBSEQUEI~T REPORT OF: SHOOTING OR ACIDIZING [ I ' ABANDONMENTS (Other) " ' (NoT~: Report results of. multiple completion On Well Completion or Recompletion Report and Log form.) 17. DESCRIBE PROPOSED OR COMPLETED OPERATIONS (Clearly state all pertinent details, and give pertinent' dates, ln.cludlng estimated date of starting any proposed work. If well is directionally drilled, give. subsurface locations and measured and true vertical depths:for all markers and -.ones perti- nent to this work.) * , Beaver Creek #2 is currently being plugged back to the Kenai formation acc'ording Sundry Notice dated 12/18/67. Following setting of the final plug!'i, at .approximatel~ 6,000' it is proposed that the well be completed as a gas producer~..:from the productive Kenai zones using the following 'procedure' '-- l) Perforate 5,155-5,220'. and 5,229-5,244' wit'h four jets per:foot' (note:' zone is now perforated 5,155-5,175', but this section' will be re-perforated, due to the possi- bility, of mud damage during testing and plugging, of.'th~ HemlO~K).,.(.', 2) Run 9-5/8" GUiberson hydraulic-set type RH-1 packer on.3-1/2.:'i'.;iiO'.D:, 9..'2~,....N;80, buttress tubing with one joint tubing below the packer. "Lan~i.tp,a~er at~'app6oxi- mately 5,080' with the bottom of the .tailpipe'at 5,112' . ~ ~,~.,"-'*~; ~-" l.,~ ~, ~'~i · Install 5,000 psi xmas tree. ' Displace mud in annulus with treated'fresh"water,' 3) 4) 5) 6) 7) Set packer hydraulically. test. Fl ow well to clean up. Conduct 4-point open flow potential 18. I hereby certify that the foregoing is true and correct · IT~-~ District Operations Man~er'~= ;~' !12/22/67 i;. ~ "*' .'" '(This space for Federal~ Or State office ~ise) CONDXTIONS OF ~PP'ROVAI~ XP AN~: . ' *See Instructions on Reverse Side Form 9-331 (May 1963) lk~TED .STATES ' sun~IT (Other instructi DEPART[V, ,T OF THE INTERIOR verse side) GEOLOGICAL SURVEY SUNDRY NOTICES AND REPORTS ON WELLS (Do not use this form for proposals to drill or to deepen or plug back to a difgerent reservoir. Use "APPLICATION FOR PERMIT--" for such proposals.) 1. 7.'UNIT AOREE~tENT ~A~xm 0IL , WE,.L [_]~'ELL~AS [] : OTHER ' Beaver Creek Unit 2. NAME OF OPERATOR 8. FAR~% OR LEASE NAME . ;,iarathon 0il Company (Operator) · Beaver Cree~ Uni~ 3. ADDRESS OF OPERATOR ~ 9.-,~Wi~LL NO. ~ "~,~ P. 0. Box 2.80, Anchorage, Alaska 99501 LOCATION OF WELL (Repor~ location clearly and in accordance with any State requirement~.* See also space 17 below.) At surface 590' south and 1,979' west of NE corner of Sec 2, T6N, RIOW, S.M. . 14. PIURZ~IXT NO. 1$. E~m. VA~ONS (Show whether DF, ET, OP~ et~) 140.3' GR 16. Form approved. 4~-Rl,i .~ Budget Bureau No. 5. LEASE DESIONATION AND SERIAL NO. ~ A-028118 10,.FIELD AND POOL~ OR WILDCA~ Wi l dcat 8EO., T., R., M;, OR BLK. AND Sec 3' TCN ~R10W SM Check Approp;Jote Box To Indicate Nature o~ Notice, RepOrt, or Otl~ Data NOTICE O~' IN~ENI~ION TO: TEST WATER SHUT-OFF FRACTURE TREAT SHOOT OR ACIDIZE REPAIR WELL . PULL OR AL~ER ~ ULTIPLE COMPLETE ABA"DON' Heml ack CHANGE PLANS (Other) · SUSSEOUE~>'R~'~B~ ov'i ', , FRACTURE TREAT)~ENT ALTEBIiNG CASING SHOOTING OR ACIDIZING ';~:" AS~kNPOIqMENTe (Other) (NOTE: Report results of m'ultiple completion on' Well Completion or Recompletion' Report and ~og form.) 17. DESCRIBE I'nOPOS~.O OR COMPLETED OPERATIONS (Clearly state all pertinent details, and give pertinent'~dates, including estimated date of starting any proposed work. If well is directionally drilled, give subsurface loc~tions and measured and true vertical depths~'for all markers· and zones ~ertl- .c., ~ ~i~wor~>* : Harathon Oil Company has completed tests of the Hemlock Zone, havi:ng:(encount,eredl mechanical troubles after receiving indiCations that the perforated interV~l'ii.:14, i.942!i'~l~5',386',~was !-nd/- :~0~iplete ithe wel 1 in thesub-commercial.Kenai gas sands.Wen°w request permissi°n t° plug the Heml°cki! As repovted in Leesee's Monthly Report of Operations for November,. 1967, the. well com- menced flowing by. gas lift November 30 after the procedure which ha'd been:.~ubmi'tted to you by Sundry Notice dated November 8, 1967 had been followed, i DUring] the period November 30 through December 6 the'.well either flowed or was swabbed]~W, ithF~a ,total fluid ...... recovery of 11,7. barrels oil and 335 barrels mud and water. r The Hemlock was reperforated as follows on December 7: 14,942.'~1'4!,:962:.", 14'994'i-15,009'; 15,037'-15,057', 15,085'-15,100', 15,160'-15,185', and 15,290'-15!'~3!0''-. AlSo. lanew interval 15 130'-15,160' was perforated. The above intervals ~e.~.,].Shot W. itb:.!oUr jets per foot. During the period December 7 through December 12 the well eithei~',(f.1}0Wed .Or' was?S'.wabbed witheR total fluid recovery of 120 barrels oil and 359 barrels mud;and Water,~]:/:'tDuring the final flow periods the well produced mostly gas which carriedquantities~",ofmud.and sand which were exceedingly abrasive, preventing further flowing'~).Of flowing characteristics indicated that. the tubing was open to the~'gas'.'fi~lled~annulus, Drobabl'v throuch a cut-out gas lift valve. . :~,~:, ~;,~ .!]:]. ~.'.! i. ':'" . 118. I hereby'c~e.~at-the foregoing is true .and'" correct con t i n u ed SIGNED x ~ (This space for Federal or Sts/te o~e u~e)~ f. CONDITIONS OF APPROV~ ~ ~: · IT'.~. District Operations Managdt'~i~.il ;~i!12/18/67 · ~e Insffudions on Reveme Side ., Form 9-331 (May 1963) /'~)ITED STATES s~m~ IN T~ 'iiC,TE. (Other lnstruct~_~ on re- DEPARTMENT Of THE INTERIOR verse side) GEOLOGICAL SURVEY Form approved. Budget Bureau No. 42-R1424. LEASE DESIGNATION AND SERIAL NO. A-028118 6. IF INDIAN, ALLOTTEE OR TRIBE NAME SUNDRY NOTICES AND REPORTS ON WELLS (Do not use this form for proposals to drill or to deepen or plug back to a dtfl~erent reservoir. USe "APPLICATION FOR PERMIT--" for such Proposals.) 1. ~.. UNIT,AOaEEMENT NAMn o,~,,.~L [-] ~*Sw,L,, [] OT.ER Beaver Creek Unit 2. NAME OF OPERATOR 8. FARM OR LEASE NAME Marathon Oil Company (Operator) "" Beaver'.'Creek Unit ... a. ADDRESS OF OPERATOR 9. WELL NO. ' .. - P. 0. BOx 2380, Anchorage, Alaska 99501 , 2 - -' 4. LOCATION OF XVEL~. (Report location clearly and in accordance with any State requlrementL· See also space 17 below.}: At surface 590' soUth and 1,979' west of NE corner of Sec. 3, T6~, RIOW, SM 14. PERbIIT NO. 15. EL~VA~ONS (Show whether DF, aT, os, et~) 140.3 GR !0,. FIELD AND POOL; OR WILDCAT · -- Wildcat - 11. sue., T., R., H., OR BLK. AND -~:' -- RI0W SM (. .: '- ,. . ~ .,... :~2.' COUNT, o, ~i~.~! la. a,iTn :"" .Kenai' ,,. ,., .J ~Alaska 16. Check Appropriote Box To Indicate Noture of Notice, Report, or Other Data ': NOTICE OF IIqTENTIOlq TO: SUBSEQUENT' RBPOR'J~ OF TEST WATER SHUT'OFF FRACTURE TREAT SHOOT OR ACIDIZE REPAIR WELL (Other) PULL OR ALTER CASINO CHANGE 'PLANS WATER SHUT-OFF ..~ REPAIRING WELL FRACTURE TREATMENT , ALTERING CAfJlN0 SHOOTING OR ACIDIZING &RANDONMENTm · (Other) NoTE: Report results of multiple completion on Well ompletion or Recompletion RepOrt and Log form.) 17. o~scaInE I'nOPOSEO OR COMPLETED OPERATIONS (Clearly state all pertinent details, and give pertinent dates, including estimated date of starting any proposed work, If well is directionally drilled, give subsurface locations and measured and true veitical idepths.-for all markers and sones pe~d- nen,~* ~iswor~-)* Continued from Page 1 il '::,i ~:i~ iil i~ Cumulative production during the 13-day test period was thus 237 barrel's 0~1 a'nd:/69~ barrels mud and water. Though the mud and water was mostly load. f!)uid';.. ........ the... would not sustain a commer~¢al oil completion. ~ "-~ ° J cT' ,] ~ ,... Marathon proposes: to abandon the Hemlock as follows, starting 1) Set blanking plug at. 14,827' in tubing stinger below ]ower 'packer.i'!' -~ 2) Kil] tubing and casing with mud. ii!~: ..i~. '? 3) Set 100' cement plug in 7" casing on top of packer at 14,812"~:,:to Seal !He~]Ock per- rotations .14,942'-15,386'. P]ug to be mixed with 25% excess ~cement; top 'of; Plug at 14,700' and bottom at 14,812' ~'~"::"~' [, .... 4) Tag plug with tubing after sufficient ~.O.C. time. .~:: .... . :~ 5) Set 200' cement .plug (100' above and 100' below) across l~ner i:,top: .between..7-~.:.~'liner and 9-5/8" casing at 8,594'. Plug to be mixed with 25% exces:~!::¢'em~nt;~'top ~.o!f plug at 6) Tag plug with tubing after ;ufficient W.0.C. time. :-~;-'~·','~ ?- 7) Set cast iron bridge plug in 9-5/8" casing at approximately 6~,'~0O!'~t~ ('in!S~r-e'¥complete casA ng seal bel ow the Kenai sand. L~: o .... · 8) Recomplete weill as Kenai gas producer. .: ;:., .. ' ,:~,'.~ ~:~., ...... :: , -~' Another Sundry Notice will be submitted for the Kenai recomp'leti0nli,'pCiior ~',1;° commencing that operati on. 18. I hereby certify that the foregoing is true and correct TITLE (This space for Federa~ °~St~'e ofll~oe use) CONDITIONS OF ~pPROVAz~ IF ~: District Operations Mana'ger~a~,:; ;i2/18/67 '.'~ ~.: '~ ,,~ :',.:,..., ,.: ,. ,.- -, ;~ ..' · ~. ,,'&, /, , , ,' "'~'-- ~-' h~'. t,." '~ '- ~,4 ,,- ¢,, ~ .... .' ,-4 ,, ~:: -~ - ~.. .,..',.; ~,, DAT]G;. · *See Instructions on Reverse Side ! P.O. BOX 2127 * ANCHORAGE. ALASKA · TRANSMITTAL ]967 Division of ~.~nes & Minerals Mr, TOm.. Marshall 3001 Procupine ~rive State of glaska Anchorage Dear Sir: / We have transmitted this date via pc-?or.~! r~,q~vary.,,~,16 boxes) ~d samples from the: No. I East Tyonek-State 17588 /~' 6~8 - i~ (six bo×~s) No. 1 Cook Inlet-State 17~91_ '~UO~~--'-----~ix boxes Beaver Creek Uzd. t // 2 2260- 1~700 13120 - 13810 (four boxes) samples lost in transit RECEIVED OEC 15.1967 DIVISION OF MINES & MINERAL8 ANCHORAGE Please acknowledge receipt by returning one copy of khis transmittal. Very truly your s, Ronald G. ~' ' .oro c ~way American Strattgraphic Co. Receipt acknowledged by date Remarks: . Form~-3~l (May 1963) ~ITED STATES surm~ (Other lnstrucL DEPARTb,~.NT oF THE INTERIOR verse side) GEOLOGICAL SURVEY SUNDRY NOTICES AND REPORTS ON WELLS (Do not use this form for proposals to drill or to deepen or plug back to a difl~ereut reservoir. Use "APPLICATION FOR PERMIT--" for such proposals.) Form approved. Budget Bureau No. 42-R1424. 5. LEASE DESIGNATION AND Si/~RIAL NO. A-028118 -: 1. 7. UNIT AGREEMENT NAME OIL ~ OAS ~] OTHER W~LL WELL Beaver Creek Unit 2. NAME OF OPERATOR 8. FARM OR LEASE NAME Marathon 0il Company (Operator) Beaver. Creek :-Unit 731 I Street, Anchorage, Alaska 9950l ' 2. ' 4. LOCATION OF WELL (Report location clearly and in accordance with any State requirements.* See also space 17 below.) At surface 14. PERMIT NO. 590' south and 1,979' west of NE corner of Sec. 3, T6N, R10W. S.M. 15. ELEVATIONS (Show whether Er. aT, oR, et~.) 140.3' GR 10. FIELD AND POOL, OR WILDCAT .. Wi l dcat 11. 8mC., ~., R., M., OR BL~. SURVEY OR AR~A . 'Sec 3 T6N RI0W SM 12. COUNTY OR PARIEH{ 13. STATE ; .... Boro{ · ~ .Kenai ^] aska ,, 16. Check Appropriate Box To Indicate Nature of Notice, Report, or C)ttie~ Data NOTICE 0F INTENTION TO: FRACTURE TREAT MULTIPLE COMPLETE SHOOT OR ACIDIZE ABANDON$ REPAIR WELL CHANGE PLANS - (Other) Additional Casing Liner SUESE~UE.~:;"~poRT FRACTURE TREATMENT ALTERING CASING SHOOTING OR ACIDIZINO AEANDONMENTs · (Other) NoTE: Report results of multiple completion' on Well ompletion or Recompletion Report and Log form.) 17. DESCRIEE PROPOSED OR COMPLETED OPERATIONS (Clearly state all pertinent details, and give pertinent dates, including estimated date of starting any proposed work. If well ia directionally drille~ give subsurface locations and measured and true vertical depths, for all markers and zones perti- nent to this work-) * j ,;.); '.-~ j.- it.. :.:- ~, ,. ,[ [ j .- .... · . ,. v. " II A 7 liner has been run and cemented to a depth of 14,439' 'as Was proposed on the Sundry Notice dated October 19, 1967. Since that. time the well has been drilled to a total depth of 15,697'. It is now p~op0~ed .to rune 5" - · ~ to~ ~o't'al depth,- o.d 18#/ft F.j. Hydril liner from approximately. 15,420~; The liner will be cemented with 50 sacks of cement. [: ~' - ': ' ~-' (J ~:: . Verbal approval to'.run this liner was obtained from Mr. Bi],'l~Wunnicke"on;!';~ November ] 1, ] 967..~ ".., ,~ , ~ ~-~ ': ..... 18. I hereby certify that the foregoing is true and correct Thi ...... ' ~-- ( S space for Federa~ o~Sta]te office use) CONDITIONS O:~ ~APPROV~ ~ ~ i' ' · ~L~ Ac .D~st. erations · ,.~ ~11 7/67 ' ',' [;~ ~. - ........... . . TITLE · See Instructions on Revere Side NOV 20 1967 Attachment to the Sundry Notice dated November 8, 1967 submitted to request permission to perform the testing in the Hemlock zone" in Beaver Creek Well #2. DST #l to test 7" liner perforations 15,356'-15,386', 15,280'--15,345', 15,158'-15,248' with four jets per foot. Ran Halliburton test tools and set at 15,124'. Ran 1,O00' of water cushion. Opened tool for 5 minutes and had weak blow. Closed tool', for a 2 hour and 5 minute initial shutin. Opened tool and had immediate weak blow with moderate blow in 30 minutes and strong blow in 1 hOur. Left tool open for ll hours and 29 minutes with no fluid o~ gas to surface. Took 3 hour final SIP and pulled tools. Reversed out 7 barrels of water cushion, 5 barrels of mud, and 45 barrels of oil. ISIP 7,518#, IFP 1,446#, final FFP 3,179#, and FSIP 6,942#. Ran and set bridge plug at 15,120'. Perforated for DST #2 at 14,492'-14,962', 14,964'-14,974' ,- 14,990'-15,020', 15,033'-15,058', 15,063'-15,073', and 15,080'-15,100'. Ran Halliburton test tools and set at 14,907' .-.." ~Ran.-I ,000' water cushion. Opened tool for 5 minutes and. had weak blow. Closed tool for 2 hours and 5 minutes to take initial shutin. Opened tool and had good blow immediately, strong blow in 15 minutes and gas to surface in 1 hour and 25 minutes. Left tool open 26-1/2 hours and recovered no fluid. Gas flow to small 'to measure. Took' 3 hour and 5 minutes final SIP. Reversed out 7 barrels of water cushion, 3 barrels of mud, and 138 barrels of oil. ISIP 7,326#, IFP 1,110#, FFP 5,354#, FSIP 7,086#, and BHT 196°F. Well was then drilled to a TD of 15,697' to evaluate the formations existing below the 7" casing shoe. RECE'IVED NOV ! 1967 DIVISION OF MINES & MINERA~ ANCHORAGE · !::';('-A~er, ho'le haS"been c'leaned up, run gauge ring with Junk baske~ to 14,87~' . "3o'.) ,Pick up drillable pa~ker 'complete with tail pipe assembly ~n~ set on' wire · ',(;!i[,". line at 'approximately 14,800'. . ..... · · , . . ~.? Drop retrievable ~unk basket md perforate Upper Een~i C~s Sands at 'approx. '~ii:::'~, ]55"'~,175:' (correlative to completion perforations in Beaver Creek · '~: J · ~- .. · Retrieve ~unk b~sket am~ run tubing with RE-1 packer, 2 circulating valves, 'i.~i~l Otis "X" nipple, an~ unknown aumbe~ of gas lif~ valves, mounte~ om ?:of sleeve ty~e .mandrels. ''-f: ' :. ~?!... . .. · :- f~. '~ ...? 6.? Run all sliding sleeve'.type gas ii maadrels wit~ sleeves im _close~°''',,. '''~: '!ii'~:i'.po.sition. ... - -.. ....:.. :.~;,...,,~. ,e . . ' Run lower circulating valve im the o~pen, positiom an~ ~e ut~e~ · · '.'~ .'1 ' · .~:~i·i:'valve in. the...close~ position. · · ,.;: i~ :.i .. ~.,,:.,. :.: · · . - q ..:~y.' ..' ". '.ih:! ~ tubi~ in'permaaeat ~cker.aa~ iastall Christmms tree. · .x....,~ 9'.:;J:~ Seat plug ia'"X" nipple below lower' cir~ulmting valve. ' "ii: · ":;-'~ · . . '. . ~.~ . . ' · , ' 'i:~ . , j. ' , .." · . ~. ,",.. .... :' ..~.,~ . , " ..... ,'. U,'-, ",. ' -,:.'. '"'"" ' "' ' Ll.:.?¢lose lo.er c~-.rc valve... ',",: , '~'', · .... ,i::',',,'"':'""?:~.~, , .,~...,. · . . . !'·.:' . . ~,?..,, !:'!i'i'." " " "' · ".. "; '.· .:, "i,: · . ... . .. · ...,:.... en upper circula.ting valve an~ c~ean .up ~as zones. - ": --.' ...... ?.~;. · - ..- ' ':'~.; ;.1~"['( Close .upper circulating valve an~ 'retrieve:Blanking plug, .an~'open..lower .... ~' . i~iiii circulating valve. ' : "" '.' - 4 . . . · ,, [:~o[i',.'Open 'n'ecess~ry sliding S~eeYes on.ga~.:lif~ mandrels a~ s~a~., lf~-~ng'fl~m' '~he Hemlock:, found~tion.'~:i:" · :: .... .. '..,:;-' ,. x:....,,.. :.,, .. ,.;' :' ??':.'~....:....., · t~-'' ' ,: ...... . ,;t; ' ::~?'. ,,'~,;.%." · :.,' "~,'. , ',-'.'. . :'{:':' "' '4~' 'i~:.: ;.',",["' '" ","'~ " '" "' ottom' ::': :" valve'.[ &~e~.' '" 50' ":. ' . . · ' ' ,K "' {'('.1. "' ':'.". ii '..'.' : . '. ; i: '~ "'" -"'I' ' "" -, ~' . - · :'.,",' ." "i'.".? .. . ;.. . : ~'. '.'-", :.; · ~';, ' "T . ?; · L'. .... ;:' , ' :"? ,- i :;-: ,J. :;.'[,;' ,'~,,,..., ,...,. '.'-[,; .~..',,.,.:t,,.'~ ;....'~..'..'.":~,~.,%~ : t,.:, ~. ' .' "' ,', · ,:'.'" ,r:., '~,'~' ' ; .,"b ', ~,. "~"'"": ' COMPLETION PROCEDURE : '~';' ".":'; . ...,: · . . PROPOSED , ' ,; ' ',' '~ , ;', . .. ,~,'.' .-. ' '. ' ........ - ........ - :' ' ,1' i'"" ' ",' · ": , ' ' .,'.: ' .1 · ~'.. '; ' '; ,' -' ' :",';": ~"~ '.; .';., '.'..'7-t..-,:). ~,,,:.:;',:,, ..:., .,,: - · ' . .,....-":..." ,:'~ ' ," ,...,,:. :-. '...',. .. ',. " ~ . ,,. .., .... ',*d..j,..b,.' ':'.".,',q~ '.. ,. ;,,', .... ';: .". , ,'Z'.' · :"'.,';!,'~'~,:~: ::,i!..,. :....' '...'..'.,. '... :.,, .i ,........ : ~eaver uree~ un~ :,.,?,; · ,.,. ,....: .'?.',.-'..: :" ...' -' , ':,.':.; .... ~" ," '-,: ,..i i,;~:i.",!".. ""',",' ' : , ' t' '..' ' '. ' , . . , ' ,'... " .. ' " - '.,: .',':~', ' ' .". , '. - · ' "-" · :, ·'. '. ' ". '.' ' ', 'e' - :,'t , '~' · ~..'~:',': ' '..,. , ,- . .. '.' ' .W,e.l~ 'No. 2 .. '.' '? /: ' '' ... : . '-,",'.:"x;:~i...,, :-':i?.:'.: from further evaluation of the Hemlock. . ' ' -r , · GAS LIFT,,,VALVE ARRANGEMENT No;'"' 1 ~..~,..: 14, 700 No' 2.~/'ili.{i ' 14,380 .:'v'. .. No .'. 3 1 i.'.":..'1 13,930 No'.. '13`, 400 .],,.': No. 5 ?:,-.1.2,,650 1' ;?.. No.--6 .. .... !i': ' :':' "T ti'. ~o. ?:.. i.,,...: ~., 8oo ;..,:. ~To. '~ ~'''~:.,.,., ,., ;3.o, V0O. i:'i ~i' ,:.'".r,-:' No....'9 ~':. 7, ?'50 ~:".i~ i:. r,;' ;~iIN'o.i: ~.",:: .~,;'700: :~.?? ,,,'. :::; ::': ,: · PROPOSED DOWNHOLE INSTALLATION Hemlock &' ?""~at Gas Sanda Beave~oreek Un~t~ Wo3~i. No. 2 · .-,,.' · :'/I.' ...~.;. ~ '/~...: .. . ,'. ~ ~ ". -~ Form 9-331 · .... (May 1963) ~ . · .. 1. ~'~'TED STATES s~mT ~N DEPART[~,~T Of THE INTERIORverse(Otherstde)lnstruct~' GEOLOGICAL SURVEY !CATE' 011 re.. SUNDRY NOTICES AND REPORTS ON WELLS (Do not use this form for proposals to drill or to deepen or plug back to a different reservoir. Us~ "APPLICATION FOR PERMIT--" for such OIL ~_~ GAS WELL . IX] WELL 2. NAME OP OPERATOR OTHER Marathon 0il Company ' '8. ADDRESS OF OPERATOR (Operator) 731 I Street,-Anchorage, Alaska 99501 LOCATION OF WELL (Report location clearly..knd in accordance with any State requirements.* See also space 17 below.) At surface 590, south and 1,979'-west of NE corner of Section 3, T6N, RIOW, S.M. 14. PERMIT NO. 1 J 15. EL~VATIONEJ (Show whether DF, RT, 01~ et~) Form approved. Budget Bureau No. 42-R142S. "5. LEAS~ ~ESmNATION AND sEar~L A-028118 6~';'lF. INDIAN, ALLOTTEE OR TRIBE NAMi~ ['7 .~. ,..~ -: ~.. :. ~.i '~ "-' ·' ' ' :: ' ' · :7.' UNIT:AOREE~fENT' NAMI ~ ...... aeave~ CCeek ~n~ ;'.~' -' Beaver:Creek Unit 5./w~,.,. No .... ...-:. -:. " " ...... ' ,.::,. ~' .. ~'"' ' W 11/aI~C., T., a.~ M., OR BLK. AND '~ ,.~ ? flUBVBY OR AR~A'~ J ' " ~: .... =~ ~,,5:. Alaska ..: 140.3' GR -: r~ :.:' :': K~na~:m :.J Appropriate Box To Indicate Nature of Notice, Report, or Otli~ D~ta ;~ ::; ~ :. :~. -.. - - FRACTURE TREAT MULTIPLE COMPI,ETB 8HOOT OR ACIDIZE ABANDON· REPAIR. WELL CHANGE PLAN8 ::.'::..- *See Instructions on Reverse Side (This space 'for Federal or State rice use) APPROVED BY ' m ' ' ' :' :j-' - TITLE CONDITION8 OF IPPROV~ IF ANY': ' .~. "/.-,..- Mara~hon,..requests permission to test the Hemlock Zone by ga~ 1 i~f, tl~g. ~1"~: h~.':'~':'gas · t'sft gas is 'to be supplied by this ~ell from [he 5,100' gas zone!~ theY. HemlOc~:.Zone presen¢ly perforated through [he 7" liner a[ 15,158'-15,248'!. produced 45 barrels of oil ingo the drill pipe bu~ failed ¢o was set at 15,120' ~' The 7" line~ ~as t~en perforated at ~4,942~-~4,96Z ~ ~4,964 -:~4~74: ~ ~.4~990,.. 15,0ZO'~ ~5~033'-15,058~ 15,063'-~5,073'~ and prOduced 138 barrels of oil into the drill pipe but the well In order to test and to fully, evaluate the productivity of thi, S: well i ~t ~bs[ ,ibe produced by a~tificial lift. The attached schematic drawing afid~,pl:an Of<operation are presented to-indicate how this well can be t'ested by artifi:C'ial~ li~.tj~];.~:l%j, is. . Marathon's intention to use .this procedure for testing purpos~S:~,~On.l:Y. ~ %:, ~.~ The gas used to artificially test this well will be flared, h'O~eF, Fii ~iJi~ ~be measured with an orifice meter for accounting purposes. Autho'r]i'zat]idn:~'t~.~te~'% this well is requested for a period of sixty days. A selected[~eq~jo]O:Fin~;~heTgas zone will be perforated to supply gas for gas lift purposes. ~ ~ShO~.l d: the. ,.teSt prove that this well does not have commercial production, then~/ith~'~e$l}oCk~LZd~e will be Dlu~qed'and abandoned in coap]iance ~ith USOS r 9ulat~o_n:S~,~ 18. I hereby eeriK~' ~at=~e for6golng ts ~ue ~d-corr.- (NOT~: Report results of. multiple completion on: Well (Other) Testi n(] ~em] oc~ Zone Completion or Rec0mplet,ion Report and Log form.) DESCRIBE I'aoPosEO OR CO~IPLmTEO OPERATIONS (Clearly state all pertinent details, and give pertinent dE'tee, including estimated date of starting any nentPr°p°sedto thlsW°rk.work.)If* well is directionally driile~ give subsurface loc~tions, and measured and true vertical [_dept?. for all markers and sones peril- Form 9-331 (May 1963) ?'"~TED STATES su~mT zN ~'r~'C~ *yE' (Other instruct, on re- DEPARTIv,,..,,IT OF THE INTERIOR verse stde) GEOLO(~iCAL SURVEY SUNDRY NOTICES AND REPORTS ON WELLS (Do not use this form for proposals to drill or to deepen or plug back to a different reservoir. Use "APPLICATION FOR PERMITm" for such proposals.) Form approved. Budget Bureau I/o. 42-R1424. 5. LEASE DESIONATION AND EIERIAL NO. A-028118 6.-IF INDIAN, ALLOTTEE OR TRIBE NAME . 1, _ O,L [_]WELLOAS k-----I OT.ER Beaver C~'eek Unit WELL 8. FARM OR LEASE NAME 2. NAME OF OPERATOR Harathon 0il Company (Operator). Beaver C~eek Unit ~, ADDRESS OF OPERATOR 9. WELL NO. 731 I Street, Anchorage, Alaska 99501 .2 LOCATION OF WELL (Report location clearly and in accordance with any State requirements.* See also space 17 below.) At surface 590' south and 1,979' west of NE corner of Section 3, T6N, R10W, S.M. 14. PERMIT NO. 16. 10. FIELD AND POOL~ OR WILDCAT - Wildcat 11:. SEC., T., R., M., OR BLK. AND "' ~ . SURVEY OR AR~A · "~ :~SeC 3 'T6N R10W SM 15. ELEVATIONS (Show whether OF, Rr, o~, etc.) 140:3' GR Check' Appropriate Box To Indicate Nature of Notice, Report, or otl~er Data 12; COUNTY OR P~ISH[ 13. ~ITATE Kenai '"1 Alaska NOTICE OF INTENTION TO: TEST WATER SHU~'OFF FRACTURE TREAT SHOOT OR ACIDIZE REPAIR WELL MULTIPLE COMPLETE ABANDON* CHANGE PLANS (Other) SUBSEqUEN~'aEPOaT O~: , ' WATER 8HUT-0FF [?:' REPAIRINO WELL FRACTURE TREATMENT ,.:. '" ALTERI'NO CASINO I~ItOOTINO OR ACIDIZINO : ABANDONMENT*, (Other) Casi no Procram NOTE: Report results of n~ultiple completion on Well ompletion or Recompletion Report and Log form.) 17. DESCRIBE PROPOSED OR COMPLETED OPERATIONS (Clearly state all pertinent details, and give pertinent dates, including estimated date of starting any proposed work. If well is directionally drilled, give subsurface locations and measured and true vertical depths for all markers and zones perti- 10/19/67 - 10/21/67 10/23/67 - 10/24/67 - 10/26/67 - 10/28/67 - 11/1/67 - 18. I hereby certify tl~at the foregoing is true and correct Ran 160 its 7", 29~ and 32/b N-80 and P-110 X-line liner:: with shoe:<i&tl' 15,439', landing collar at 15,393', and top of liner packer at 8,59.4'.. -Cemented ~7'' liner with 650 sx with 120# retarder and 650# friction reducer.. Ran'cem'ent bond log, gamma ray, and collar locator log. PBTD 1'5,390'':r~,~,.,,:: Top of cement . .",. .=: ~, - __ in annulus at 13,800'. - -~ .... ~ - " Perforated 15,356'-15,386', 15,285'-15,345', and 15 158,,15,248:'.. .. wi. th-~4~. ... jets per foot· . Drill stem tested above perforated intervals with packer set at 15,124'. Tool open ll hrs 29 min. No gas or fluid to surface.~.:'Recovered 8'bbls ...... water cushion, 5 bbls load muddy water· and 45 bbls 33°, APL oil. Set bridge plug on wireline at 15,120'. Perforated 14/,942[".-14,962-";"q4,964'- 14,974', 14,990'-15,020', 15,033'-15,058', 15,063'-15;073[(',~!:;~ .. ..~ .~ and. 1'5','080'-....... 15,100' with 4 jets per foot. ~ ~'! ~:.~' Drill stem tested above perforated intervals with 'pac~er.'.['S~"t. a.t, 14;907'. Tool open 26 hrs 30 min. Gas to surface in 1 hr 25 minutes-..--NO .flUid to surface Recovered 7 bbls water cushion, 3 bbls mud ,'?!and ;'138:; bbls 35° APl oil · '-=" :'~'. ...... ' Ori 1 led bridge plug landing col l ar, and shoe. ,. ;-';,.-, .',: ;:.' ::,'= Drilling 6" hole at 15,546'. ::?~?::" .... .::' ':' ~zT,.EDistrict Operations Mana_~erf;'.B*~, ~' 11/2/67 - ¥, 'if; ~'. TITLE (This space for Federal o~r S~tate pffice use) CONDITIONS OF APPROVAL, I~ ANY: *See Instructions on Reverse Side DIVISION OF MINES ANC..NOI~AGE '~-.~ i ~ Formn ~5~1"t'5 approved. , Budget Bureau No. 42-R356.5. ~,o o Anchorage UNITED STATES ~ mc~ ............................ DSPARTMENT OF THE INTERIOR ~,u,,~ .... ~:~e.L~ ............ ~OLOG~C~ SU~VSY u,,, .............. .~.~L.~~..~nit LESSEE'S MONTHLY REPORT OF OPERATIONS . , Alaska Kenai Borough, Wildcat Well State .................................. Oo~nty ..................................... Field ................................................................... Tke followi~ is a eoKrept.report of operations p~d prod~otio~ (inel~din~ drillD~ and produein~ uc:ooer O! wells) for the mont~ of ' , 19 ................................................................................... , ~l ~ e n t ' s address ................ .7. .3_ .l. : . _ I_ . . .S. .~. .r. .e. .e. .t_ . .......................... C o m p a n y . .M. .a. .r. .a. .t_ .h. .o. .n. . . .9.i. .]. . . .C. .o. .m. ~?. .r) ~. ................... Anchorage, Alaska 99501 Si~ed ....... ..~__.J_..~ ................ ........................................... ~7225~1l'~ ................................... ~/~ent's title District .Op. erations Manager P~,one ................................................................................... ' .................................................... lcer. 345', tce SEC. AND BARREL~ oF'OIL I (]RAVITY (Ill thousands) (~ASOLINE WATER (If (I! drillinz, depth; if shot down, cause: ]4 or ]4 Twr. R~NOE WgL~ Dars CU. F~. og (]AS GALLONS OY BARRELS O~ REMARKS , ~]'O. Pno~voeao, , I RECOVERED none, so state) date ~nd resultcontentOf oftestgas)f°r 'NF-/NW 6N lOW 2 lO/I-.lO/14 ')ril ed 8-1/2" hole ~rom 4,935' to 15,431'. Ran La~e-Wells IES, Dual [ndu~:tionI Sonic, and Den:',ity logs. Took 4 ;idewall cores from interw · 5,1l~,,O'-l,~ ,396' lO/l.~;-lO/18 )ri led' 8-1/2" ~ole from 5,431' to 15,439'. Ran Schlumberger IES, Di~ , netel, Soric, and Density lOgs. Took 24 sid~.,wall cores from interval .4,7~.t6'-15 4~,2,'. To):.:;of lemlock 14,940'~ '10/1.~)-10/22 ~an 60 jt~ , 29'm ~nd 3~?N-80 and P-110 X.-line li~er with shoe at _.. 5,4~9', lianding collar a'~ 15,393', and top )f liner packer at 8,594'. ;eme~ted 7" liner with 65~) sx with 120# fetal'der and 650# friction red~ , ~an (:ement bond log, gamm~.ray, and collar l¢cator. [PBTD 15,390'. To~ - )f c~ment in annulus 13,8t~0'. Perforated 15",356'-15~386', 15,285'-15,~ ~nd 15,15~'-15,248' with ,~ jets per.lfoot. 10/2~;-10/24 )rill sten tested above p~rforated Sntervals with pa~ker set at 15,124' Fool open l l hrs 29 min. /No gas or fluid to surface Recovered 8 bbl,. :- vate~ cushion, 5 bblls loalmuddy~ water, and ,[5 bbls i30 API oil. . 10/2z.-10/27 Set [ialliburton "DM" brid,.le plug on wireline at 15,120'. Perforated ' ' 4,9z.2'-14,962', 14,964' 4,974', 14,990'-15,020" 1.~,033'-15,058', i'-'. . 5,0(;3'-15,073', and 15,0;10',15,100' with 4 ,)ets per foot. Drill stem · " .:est(,d .perforated intervai s from 1~j942' to '15,000' ~.sing 1,000' of wal ~ushion Packer set at 14~,907'. ol open ';.~6 hrs 3Q min. Gas to suri · ~n 1 hr 25 min.. No fluid] to surface .Recov,.~red 7 bbls water cushion, .) bbls mud, and 138 ~bls ~)f 35°API Jil 10/2~;-10/31 Jrilled "F-M" bridge ~lug, landing col!ar,.an!t.shoe.' Drilled 6" hole · '~rom 15,429' to .1'5,5~,6' ' - · i Repo)'t of 0701) hr: 11/1/67.:. 'Drilling i~head with 6" bit. i . No~E.--There were ....... a0. .............. : .......... _. runs or sales of oil; .............. _n__o. ........................... M cu. ft. of gas sold; no ...................................... ~ ...... run~ or ~1¢~ of $~soline during the month. (Write ','no" where applicable.) No~..--Report on this form is required for each calendar month, regardless of the status of operations, and mus~ be filed in duplicate with'the supervisor by the 6th o~ the succeeding month, unless otherwise directed by the supervisor. Foxqna 9-329 (January 1950) 16--'~76~'~ u.s. GOVZlINMZN? FRiNTi#G office ~orm 9-S31 J~- - ~3Jay 1968) STATES NOilCE$ AND COo not use this ~orm for p~opo~s ~o ~:r~Zl or to deepen or ptu~ br. ek to a aif~ere,~t reservom Use "A. PPL!GA.~IO~ FOR P~Iv~I~--" *for such proposals.) approved. ?,udget 13uzc~zu No, 42--R1424. 5. LEASE DESIGNATIO)~ AND SERIAL NO. A-028118 6. IF INDIAN, ALLOTTEE OR TRIBE NAME 7. UNIT AGf:EEMENT NAME OIL ~ GAS . , WELL ~ OTYiER W~LL Beaver Creek Unit Marathon Oil Company (operator) Beaver Creek Unit 731 I Street, Anchorage~ Alaska 99501 2 4. LOCATION OF WELL (Report location clearly and in accordance with any State requirements.* See also space 17 below.) At surface 590' south and 1,979' west from NE corner of Section 3, Township 6 North, Range l0 West, SM t0, FIELD AND POOL, OR WILDCAT Wi ] dcat 11. SEC., T., R., H., OR BLK. AND SUI~VEY OR AREA, ~ .. Sec 3 T6N RI OW SM 14. PER,~IIT N0. I 15. EL~VATION~ ( Show whether Dr, RV, oa, etc.) 12. COUNT¥ 0RpARiSHI 13. STATE 140.3 GR Kcnai Al aska C[~ec4 Approp. ric~e Box To Indicate N=ture of Notice, Repor4 or O,~her Data NOTICE OF INTENTION TO: TEST WATER SHUT-OFF I t PULL OR ALTER CASING FRACTURE TREAT ~IULTIPLE COMPLETE SHOOT OR ACIDZZE ABANDON* REPAIR %YELL ~ ] ' CHANGE PLANS (Other)Casing rogram SUBSEQUENT REPORT OF: . ' WATER SHUT-0FP REPAIRING WELL FRACTURE TREATMENT ALTERING CASING S}KOOTINO OR ACIDIZING ABANDONMENT.~ (Other) (NOTE: Report results of multiple completion on Well Completion or Recompletlon Report and Log-form.) 17. DESCRIBE I'RO?OSED OR COMPLETED OPERATIONS (Clearly state all pertinent details, and give pertinent dates, including estimated date of starting any proposed work. If well is direetionally drilled, give subsurface locm. tions and measured and true vertical depths for all markers and zones perti- nent to this work.) * .... : - On 7/7/67 Marathon submitted a modified casing program which did not provide: for casing below 8,800'. On the Application for Permit to Drill dated 6/2/67, Marathon had proposed to run a 5-1/2" liner if commercial production was found below 14,000'. This proposal is to run a 7" liner, 29# andi32#, from .approxi- mately 8,600' to a total depth .of 14,439' for the purpose of drill stem testing. one or two selected intervals in the Hemlock formation. The liner, will be cemented with 650 sacks. 18. I hereby certify that the foregoing is true and correct TITLE District Operations Manager *See Instructions on Reverse Side DI¥1~ION OF MINES UNITED STATES DEPARTMENT OF THE INTERIOR GEOLOGICAL SURVEY Form approved. ~'-" Budget Bureau No. 42-R356.5. L~NO OFrlC£ _.~[tcho~ge .... If---- u.~t ........... Be~e~..G~eek..U~] [ LESSEE'S MONTHLY REPORT OF O'PERATIONS ~tat.e ........ . .... _A__?_a__s._k__a_ .......... Oo~ty Kenai Borough .~iel~, Wildcat Well ,./ Tl~e follo~vin~ is a ~qorreet report of operatib~s a~d prod~etio~ (inoludin~ drillin~ and producin~ .'. : · ':~' wells) for the mo~tk of ..... ''' J~ent"saddress g3)JX[ Street - Marathon Oil Company ................. ............................................................................... · '~ '.', Phone ............... : ..... 272'5417 ~ent's title District Operations Manager ' ..{ · SEC. AND ' BARRELS or O~ . . ' (In thousands) · ]4 or ]4 Tw~. RANOE WELL D&I'i m Co. FT. or Gas GALLONS or BaRRE~ or REMARKS No. PAODUOBD RA Y ~ASOLINB WATER (If (If drillJ~, depth; ff shut down, ' · ' . · RECOVERED none, ~ s~te) '~E/NW 6N lOWl 2 ... ~ ': : : '" DriLled 8-1/2"'ho e from ll 791' 7' Ran L~ne-Wells dual ind~ctiCn'a~d son C,logs"Wh~[ch i~ c oil or (as sands below . . ::, . ~ri led 8-112" hole from 1~ 471' ~o 14,935'. Ran k~ne-~ell~ ~;~' d~pae~e~~. a~d ~on~c lo~ ':ook 21 ~de~all core~ o~' interval 9,044'- ... .'.~14, 164' S, nd~ v~y ~po~gy.~ .bu~ e~ma~e ~p of ~endock a~ 14,697'.. . .. ' ~ " -. ~ '~- Re ~r~ ~}f. 0700:h~' 10/1/67: Pre[a~in~ ~o drill ahe~.d ~h 8-1/~" ~. · . . . // . . · . }: , · . · . . . . , . , · , . , ~ ~ . ' . · ~ ~ { '. ~ ~ . ~ ~ . . .. . ('. ~". :-:.}~..:.~... . ~ ': ' ~; '&..~: .': . ~ . . ~' · . ~ '~.' .. ..~ . ..' . .. - )?... ':?)'.~ ~. ' .~ . ., . · ,. :.' . .,:/ · . .. .., .' :. .. ~....'..., . '~'.~f/~' · ] . ~ . '.. . - ~ ~}. .: , ~. : · ~ . .,/ ... <.~: · . -.. · . ". . ,- · .. · . . '~ .. ~ .. . .. : ~ ~ ~. .. ., . . ,~" ~ · ~ · ~ · / · . ." · · . ... , .":'1 ~. .''.. . . ~ ' ', . ' . ''. ''....]~ ."[ ~ ' . .-. ,"' . ~'['' , " ~ . . , . · . ' : · ',. ,. ~ . ~' :. .. i ' "..:' '- .. I ,- ' ' t I No~m.--There were ......... .R.~. ........................ runs or,sales of oil; no M cu. ft. of gas sold; . . no runs or sales of g~moline during the month, (Write "no}' where applio~blo.) No~.--Repo~ on th~ fo~ ,s mquir~ for ~ch ~lend~r month, ~g,r~o~.o, the s~tus of duplicate with the su~rvi~r by the 0th of the suoc~ing month, u~e~ othe~e dimo~ by the supervt~ ~rm 9-329 · ..... DIVISION OF MINES S MINE~LS UNITED STATES DEPARTMENT OF THE INTERIOR GEOLOGICAL SURVEY ~orm approved. Budget Bureau No. 42-R356.~. .......... .A_.n._c__h..o_ .r_ ~9.e.. ..... .u.... A-028083 Unit LESSEE'S MONTHLY REPORT OF OPERATIONS The fOllowD~ is a correct report of operations and production (i~cl~din~ drillin~ and producin~ wells) for the rno~th of .......... _A__u_~q_u__s_.t._ .................. ~, 19--~-7-., ............................................................................ ' 7,31 I Street . Company Marathon Oil Company ,4~e~t' s address ....................... '~'~6~'~'~'~"Xi"~-~'~'~ .......... $i~ned ...... .~_ ...~ .... ~ ................... Phone 272-5417 J~ent's title District Operations Mgr. , ' ' Co. F~. or Gas GALLONS OF BARRELS Og RE'MARKS SEC. AND r~WF' RANaE WELL Da~m BARRELS OF OIL GltavlrY GASOLINE WA?2R (If (If drilling, del)th; i! shut down, )4 oF ~ NO. rao~vcmu (In thousands) R~covsa~D none, so state) dat~ and result of t~t for IMolin® · ' content of f~ao) /NE/NW 6N 10W 2.. ' · Drill.~d 1,'-l/4" hole to 8,848'. Logged well with I-ES, gamma ray, acoustic, caliper 'dual indu(:tion, di)mete~', and density Ran 214 j¢ints 9-5~8" c~sing,.'40# to 47~, N-80 an( S-95; landed sh(~e at 8,825.14' Cemented ~ith 1,37.)-sac~:S Class G cemen: with 10% CFR-2 (friction ~'educer). Ha~ ~'ul' retur~s t~rou§hout ceme~ting. Bunped p]u§ with 2 000 psi; float held OK. Job com- plete.~ 19;'.0 hfs 8/~/67. .'Insta led 12" Seri.~s 90~ X' lO" Se~'ies 1~00 dual t~bing spo~l and nippled up blowout -prev,.~nte~'s. Test,.~d tu:Bing spool with t000 psi f(,r 15 min'.res; held OK. Ran cement bOnd~ o§; found to) of dement in ~nnulu~ at 2,508.' Teste!~ blind i'ams with $,000 ps' for 1 ~' mir~utes; he d OK Tested ~ ' - , ~ydr~l, pipe ram~', casing) choke lines, choke mani- fold, and kelly co:k wi':h 3,000 psi for 15 minute:; held OK. 'Drill:d with 8-1/21'.bit,froms,846,'. !R~port at OlO0 hrs 911/67: IJrilli. ng in siitst( sand, and clay at l'79'i'.:i'...,, i _. i . -- ..... , - "k "k k 'k * i(:' - ' ,..' . , "'~ :' ~ ' ; ' ' !i - ' ' ' · . - . · . ; · ,. 1 ,, ,, , ;one RO ' no ! -i' . ""' NoT~.--There were ...................................... runs or sales of oil; ............................................. M cu. ft. of gas ~old; ....................................... .~.9.. runs or ~l~s of gasoline during the month. (Write "no" where applicable.) · ' - NoT~.--Repo~ on 'th~ form is ~qu~ for ~eh ~lendar month, regar~ess of the status of operations, and m~t be filed in duplicate with the su~i~r by the 6~h of the sacc~ing month, u~ess othe~ise dimo~ by the supervise. _ : SEP 7 1967 DIVISION OF MINES & MINERALS Form 9-331 (May 1963) D STATES su~IT ~. ~' f,~CAT~.. (Other instruc DEPART~V~ENT OF THE INTERIOR ,e~Se side) GEOLOGICAL SURVEY SUNDRY .NOTICES AND REPORTS ON WELLS (Do not u~e this form for proposals to drill or to deepen or plug back to a different reservoir. Use "APPLICATION 'FOR PERMIT--" for such proposals.) OIL ~_~ OAS ~] WELL WELL OTHER 2. NAME OF OPERATOR Marathon 0il Company: (Operator) 3. ADDRESS OF OPERATOR 731 I Street, Anchorage, Alaska 99501 LOCATION OF WELL (Report location 'clearly and.in accordance with any State requirements.* See also space 17 below.) At surface 590' south and 1,979' west from NE corner of Section 3, Township 6 N, Range 10 W, W.M. 14. PERbIIT NO. 16. Form approved. Budget Bureau No. 42-R1424. 5. LEASE DESIGNATION AND gEnIAL NO. A-028118 . ,7.~ UNIT AGREEMENT NAbl~ ' ~ Beaver Creek Unit 8.~ FAR~ OR LEASE NAME" ~¥- Beaver Creek Unit 9. LWELL NO. : ~.~ .... 10.:.FIELD AND. POOL~ OR WILDCAT ..... Wi 1 dCat-'- "'- ,ll.t BEC., T., R.~ M.., OR "' ,.~ ' SURVEY OR ~'~'-'~ec 5~' Z6N R10W SM I 15. EL~VATIONS (Show whether DF, BT, Ge. et~) ,12; COUNTY OR P ~[ 140.3 GR .L~ ~ 'Kenai":;, '/.,!~.::~l Alaska Ch~k Appropriate Box To Indicate Nature o'~ Notice, Repo~, or Oth~ O~ta ~ :~ ~ ~, ~i. TEST WATER SHUT'OFF [-_~ PULL OR ALTER CASING ~ FRACTURE TREAT ' I~l MULTIPLE COMPLETE SHOOT OR ACIDIZE [__[ ABANDONS I~EPAIR WELL. I I CHANGE PLANS (Other)Inject water in casing annul WATER' SHUT-OFF f j REPAIRiN0' ~ELL FRACTURE TREATMENT ~:j if? ALTERING:' CASING ~-,~ ~ '.~ ABANDONMENTs SHOOTING OR ACIDIZING ~'"' ~' : ..' l , (Other) ' NOTE: Report results of. multiple completion' on Well ompletion or Recompleti,.on, Report and Log form.) 17. DESCRIBE I'ROPOSED OR COMPLETED OPERATIONS (Clearly state all pertinent details, and give pertinent ~dates, including estimated date ;of starting any proposed work. If well is directionally drilled, give subsurface locations and measured and true vertical depths for all markers' and zones pert~- nen~ t~ this work.) * ' Marathon 0il Company requests permission to inject waste dri]il w~te'r.f:in:~th'~f~'an'nul~br Space between the 13-3/8'.' casing and the 9-5/8" casing. The~l ' 8"" 3-.3~ ,~ ,~ cag~ ng~ is, se?c at 2,211' and cemented to the surface. The 9-5/S" casing is~,set.:~.v,8 ' r~:di cemented to 3 508'. It is proposed to inject this drill water~j'n~;doh-pr'oductiige Sands between 2,211-2,500'. The disposal of. this waste drill only during the-drilling of this Well to d~spose of excess ~.~ ~ ~ ',"~ .~ 18. I hereby certify that the foregoing is true and correct ~ ~f. :... (This space for Federal or State o~ce use) T~TLE Actg District TITLE AUG 1 1 1967 DIVISION OF MINES & MINERAI,~ ANCHORAGE *See Instructions on Reverse Side !8Z1'0/67 UNITED STATES DEPARTMENT OF THE INTERIOR GEOLOGICAL SURVEY LESSEE'S MONTHLY REPORT OF OPERATIONS Form approved. Budget Bureau No. L^.o OmCE ...... /~__c.b_o_.r_~g.e__ ___ .......... i ,~^~.- ,,,~,,,~, __.A:_0_2.8_0_8.3 ............. u,,- .............. B e_a.v, er_..C.r?,.e,k ..Un ,. The followin~ ,~s a qgrreet report of operations and prod~etio~ (incl~din~ drilli~ a~d prod~ein~ wells) for tke ~~.l_.~_~. ......... _~1_~1.~Z ....... : .... ', 19 ...... , ' 7 31 I, Street ................. g~'O~'{hb-fi"'O'fi'-'C-6~'~-~'~y ................... J~ e~t s address .7 ............ gnc~orag~';"g~aska ...... 9~1-'- Company ........ ~ ............................ ;...~ ........ ~r ....... , SEC. AND ]~ARREI2t OF OIL(]RAVITY GASOLINE WATER (If (If drlllinz, depth; if shut down, ~ Or ~ TWP. RAUaZ W~ PAra ' CV. F~. Or GAS GArrOte Or BARRE~ or REMARKS No. raoovo=o (~ tho~) ~ECOVERED none, so state)date ~d r~ult of t~t for g~liue ' content of ~) ~/~E/~ 6~ ~0~ Z .i ;pudde( 12-1/4" hol~ at 2015 hrs 7/ 3/67 )rillec 12-1/4" hol( to 3~0'. Opened 12-'/4" to 26". Riged up and ran 7 joints 20" )4~/ft H-40 cas' ng ~nd set at 280'. Cem{~nted with 525 sack~; of Class G with 2% :alciun Chloride). G(,od cement returns to surface. Job comp eted 02C0 hrs 7/15/67. Fested casing a)~d B;O.P. equipment ~ith ,000 psi before dr' lling shoe. Drilled 12-1/4" role t( 2,235'. Op~ned hole to 17-1/2". Rigged_up and ran 53 joints 13-3/8" 72 and )8~/ft N-80 and J-5~ casing and set at 2 ~211'. Cemented wi ;h 2,000 sacks .Class G ~ith 2~ calcium ~hl(,ride. Cement return~ on last 19 minute:; of pumping time.' Job :omplel:ed 1730 ~rs ~'/19/67. Instal.led 12" S,~rieS 900 casing head. N~ppled up B,o.P.'s )i'gh drill and tested same qith 1 500 psi. Wei~t in hole and tested pipe rams,)'casing, choke manifold, and kill lines, vdth 1,50~3 ps'. H(ld OK. Drilled 12-1/4" hole to 5, i94'. 'Rigged uR. and ran lES lo~. . , {eport at 0700 ~rs (~/1/6~ -'drilled at' 7,781' · ~ . ., . : . . . , ... ~ "~;. :(~ . . . I I i IRECEIVED I . ' I ! ~, ~ AU~, 4,1967 ' ' ' ~0 ~0 ~ot~.--~e~ ~ere ...................................... ~uns or s~le~ of oil; ............................................. ~ ~. ft. of ~ sold; ........................... ]~. ............. r,"~ or ~1~ of [~oli~e d, ri~ the month. (Write "~o" where sppliosble.) duplicate with the su~rv~r by. the 6th of the succe~ing month, u~e~ othello di~oted by the superv~or. (Jan~ 19~) - 1~7~ u.I. ~VKRNM~ ~INTiNG T7N T6N RIOW BEAVER CREEK NO.2 ~ '""'"' .\ WELL LOCATION ... ,'..._ / /,. Top ~'W Co~. J,,v',~// C¢//~'. ~'IcV. /¢0.5 ' -/- /_~ ..~C,,TL £ I" - GOO ' R'E C'E' V E D AUG g 1967' MARATHON OIL COMPANY OPERATOR BEAVER CREEK NO. 2 o , SITUATED 590 FT, SOUTH AND 1979 FT. WEST FROM THE NE COR. SECTION :3,, T6N, RIOW, S.M. , ALA'SKA " SURVEYED BY STANLEY S. McLANE, R.L.S. Dote J.une 6, 1967 Form s~z b~"l'ED STATES (May (Other instruetk ~n r~ DEPARTM~,~T Of THE INTERIOR 16. Form approved. Budget Bureau No. 42-R142~. ;~ LEASE DESIONATION AND SERIAL NO. A-028118 '(~..':iF-INDIAN,'ALLOTTEm. OR TRIBE NAME '~'- (Do not use this form for proposals to drill or to deepen or plug back to a dll[erent reservoir. Use "APPLICATION FOR PERMIT~" for such proposals.) 1. 7. 'UNIT AGEEE~IENT; NAME OIL I-'~ GAS W~L w~ . Beaver Creek Un~ 99501 (Operator) 2. NAME OF OPERATOR Marathon Oil Company ADDRESS OF OPERATOR 7.31 I Street, Anchorage, Alaska 8. 'FARM OR LEASE NAME' ""'" Be~yerlCreek Unit '" '" 2t,"9 ~I ., ~ - LOCATION OF WELL (Report location clearly and in accordance with any State reqUirements.* See also space 17 below.) At surface 590' 'south and 1,979' west from NE corner of Sec. 3, T6N, R10W, S.M. 15. E~VATIONS (Show whether DF, RV, Ge., eto.) 150' GR (estimated) 10.. FIELD AND POOL~ OR WILDCAT . .i~' . . '" :+. 'Wildcat ; ' 3i1'::SEC,, T., R., M., OR BLZ. ? Seal--". 37' T6N,* R10W, SM 12: COU~T~ ox F,:~n~ ~.~a, I la. STATE CE' ~, , ' t ,~ ~ . ,,~ Ch~k Appropriofe Box To Indicate Nature of Notice, Repod, or Other D~ta~.;' % ~ ;::,, E- 14. PERMIT NO, WATER SHUT-OFF I I~ / o: ~ REFAIRING WEL~ t--I FRACTUR~ TReAtMeNT ] [ ~- ~ ,C~ ~ ALTERING-CASING I~ld .... ~'Er .-L ' · SHOOTING OR ACIDIZlNG [ [? m O g ABANDONMENT$ (Other) Casi~..and ~mene~n~' Record omple~ton o~ Reeompleflon~ Repo~ ~n~ ~g fo~.) NOTICE OF INTENTION TO: , FRACTURE TREAT MULTIPLE COMPLETE SHOOT OR ACIDIZE ABANDON* REPAIR WELL CHANGE PLANS (Other) DESCRIBE PROPOSED OR COMPLETED OPERATIONS (Clearly state all pertinent details, and give pert,Rent"dates, including, estimated date Of starting any proposed work. If well is direct,oRally drilled, give subsurface locations and measured and true vertical depths .for all markers~ ~nd zones perti- nent to this work.) * ;~ :'~ ~ ~ [, '~ ~..... b Ran and set 20" 94#/ft H-40',grade casing to 280*. Cemented ~itk ~25: sx~Glass cement with 2% calcium Chloride. Good ~ ""' :: ': cemen: returns to surface, a_. ,~.~ Pan and set 13-3/8" 68 and 72#/it H-80 and J-55 casing to 2,211.%*-: ~Cemented':With-- 2,000 sx 'of Class G cement with 2~ calcium chloride. surface while cemen:in~. 18. I hereby certify that the foregoing is true and correct "(This space for Federal or 8ta APPROVED BY CONDITION8 OF APPROVals, IF ~: *See Instructions on Reverse Side · J U L9.-6 .IC3t DIVISION OF MINES & MINEP, AI~ ANC~O~GE Form 9-331 (May 1963) F"~qTED STATES Su~MIT m (Other instruct on DEPARTN,._AT OF THE INTERIOR verse.ide) GEOLO~iCAL SURVEY SUNDRY NOTICES AND REPORTS ON WELLS (Do not use this form for proposals to drill or to deepen or plug back to a different reservoir. Use "APPLICATION FOR PERMIT--" for such proposals.) Budge.t Bureau No. 5. LEASE DESIGNATION AND SEalAL A-028118 6. IF INDIAN, ALLOTTEE OR TRIBE NAME 1. OiL fO WELL WELL OTHER 7. UNIT AGREEMENT NAME Beaver Creek Unit 2. NAME OF OPERATOR Marathon 0il Company (Operator) ADDRESS OF OPERATOR 731 I Street, Anchorage, Alaska 99501 4. LOCATION OF WELL (Report location clearly and in accordance with any State requirements.* See also space 17 below.) At surface 590' south, and 1,979' west from NE corner of Section 3, T6N, P10W, S.M. 14. PERMIT NO. (State 67-26) I15. RL~VATIONS (Show whether DF, R?, OR, etc.) · 150 ' GR (estimated) 8. FARI~I OR LEASE NAME Beaver Creek Unit 9. WELL NO. z 2 10. FIELD AND POOL, OR WILDCAT 11. SEc., T., R., 1~., OR IaLK. ~. ,: SURVEY OR AREA · Sec. 3' T6N, R10W, S M. 18. S~'~'TE ' Kenai Borg ~l~Alaska 16. Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: FRACTURE TREAT MULTIPLE COMPLETE SHOOT OR ACIDIZE ABANDON$ REPAIR WELL CHANGE PLANS (Other) New Farm or' Lease Name SUgSEqvENT Rm'ORT OF: WATER SHUT-OFF REPAIRING WELL FRACTURE TREATMENT ' ALTERING CASING · SItOOTING OR ACIDIZING . ABANDoNMENT~ :i ,. (Other) ,- . NoTE: Report results of multiple completion on Well ompletion or Recompletion Report and Log form.) 17. OESCRIRE PROPOSED OR COMPLETED OPEaATIONS (Clearly state all pertinent details, and give pertinent· dates, including estimated date of starting any proposed work. If well is dir~ctionally driiled~ give subsurface locations and measured and true vertical depths·for .all markers and zones lyertl- nent ~o this work.) * ,~ ~? ~.:. :.. ']. :~ ~.: ,.. '- .; L;., ,::.; :z t. ,-~ 7'.:x-... --.' ri ~.~ fi: ,(. % :,.4 18. I hereby certify that the foregoing is true and correct (This space for Feder_~/,,]S~t~o~ APPROVED BY CONDITIONS OF APPROVAL, l~ ANY-' TITLE AcrE. Dist. Operations 7/19/67. TITLE /~ ,~ ' *See Instructions on Reverse Side JUL 20 1967 DIVISION OF MINES & MINE~ ~CHO~GE Form 9-331 (May 1963) U~[ TED STATES (Other instructi~ "~on re- DEPART{V }T OF THE INTERIOR vezse~lde) GEOLOGICAL SURVEY SUNDRY NOTICES AND REPORTS ON WELLS (Do not use this form for proposals to drill or to deepen or plug back to a different reservoir. Use "APPLICATIOI~ FOR PERMIT--" for such proposals,) tOorm approved. Budget iluc(:au No, 4~-R14~-4, 5. LEA~JE DESIGNATION AND SEI~IAL NO. A-028118 6. IF INDIAN, ALLOTTEE OR TRIRE NAME 7. UNIT AGREEMENT NAME OILwEL~. [~ O~S Z~ OTHER Beav_er Creek Unit WELL _ NAME OF OPERATOR 8. FAR'~2 OR LEASE NAME Marathon Oil Company' (Operator) Beaver Creek Unit 99501 ADDRESS OF OPERATOR 731 I Street, Anchorage, Alaska 4. LOCATION OF WELL (Report location clearly and in accordance with any State requirements.' See also space 17 below.) At surface 590' south and 1,979' west' from NE corner of Sec. 3, T6N, R10W, S.M. 15. EL~VATIONS (Show whether DF, RT, OR, et~) 150' GR (estimated) 14. PERMIT NO. 9.-WELL NO. · 2 '10. FIELD AND POOL~ OR WILDCAT Wildca~ 11. SEC, T, R.~ M.~ OR ELK. AND SUrtyEY OR AREA .Sec. 3, T6N, R10W, SM 12. COUNTy OR PARISI~T{ 13. STATE " Kenai . ',' 11 .{' Alaska 16. FRACTURE TREAT SHOOT OR ACIDIZE REPAIR WELL (Other) Spudded Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO : TEST WATER SHUT-OFF ~-~ PULL OR ALTER CASINO MULTIPLE COMPLETE · ABANDON$ CHANGE PLANS .. SUBSEQUENT REPORT OF: ' " WATER SHUT-OFF REPAIRING WELL FRACTURE TREATMENT ' ALTERING CASING SI:TOOTING OR ACIDIZING ABANDONMENT~ (Other) NOTE: Report results of multiple completion on-Well ompletlon or Recompletion Report and Log form.) 17. DESCRIBE PROPOSED OR COMPLETED OPERATIONS (Clearly state all pertinent details, and give pertinent'dates, including estimated date 'of starting any proposed work. If well is directJonally drilled, give zubsurface locations and measured and true vertical idepths,for all markers' and zones pertt- Spudded 12-1/4" hole at 8:15 p.m..7/13/67. ~ ~ ~.· ....... ... L~ :~ ~'.=. ~ - ~, ~ el" . .. ...'3 _ .. . 18. I hereby cert~y ~at the foregoing is ~ue and correct (This space for Feder~ or 8~te APPROVED BY CONDITIONS OF APPROVAL, IF ANY: TITLE *See nstructions on Reverse Side Jill ?.,0 1967 DIVISION OF MINES & MINERAL~ ANCHORAGE UNITED STATES DEPARTMENT Of THE INTERIOR GEOLOGICAL SURVEY 1~o r rn approved. Budget Bureau No. 42-R350.5, ~.^.o o~,~ ....... ~_c_k°.~ ......... L~^s~ Nu~ A-028083 u,,~ ............... _~E~%~E._~~... LESSEE'S MONTHLY REPORT OF OPERATIONS State .......... A.l_.a__~kB_ ........... County ......... Kena~ ................ Field ............_Mildcat-_Well .............................. The followin~ is a correct report of operations and prod~ctio~ (iz~clv~di~ drillin~ a~d prod~cir~ wells) for the~~.~_~ .............. ~/_~2~ .... ?_.'_, 19 ....... _ ........................................................................... J~e~t' s address ..................... ~._~__~~.~. ..................... ' Co~pany ...... ~g~P~..P~..~P~r~ .............. ........................................................................................................................... 4 ................................. Phone ..................................... 222=54~ .............................. Agent's title .As_Kg,__.P_iaK,___Qp_¢ra;iana__Mgr, SEC. AND ~o~4 3/NE/NW Complet water aF in cellp Now com~ 7/13/67t TWP. ELL I DAYs 'O. Paovuosn BAERELS OF OIL Iad a~d locat±o~ ter ~ell drill~ dr:Ll~:Lng equipr opeiations an{ Ord. FT. Or (}AS GALLONS Or BARRELS OF GASOLINE WATER (If (In thousands) RECOVERE~ none, so state) ! D illed water well t~ 65' and silt cella]: and cemented~ 36 Coastal Dr:.lling Co.) and s~ sting to d:.g rat-hole. Exp~ · en t pr REMARKS (if drilling, depth; if shut down, oau~e; date and result of te~t for gasoline content of g~) obtained, sufficient conductor pipe arted rigging up. ~ct to spud well on RECEIVED JUL 17 1967' D~I$10N OF MINES & MINERA~ ]' ANCHO~GE NoTE.--There were no runs or sales of oil; rio M cu. ft. of gas sold; ....................... ILO .................. runs or sales of gasoline during the month. (Write "no" where applicable.) No~E.--l~eport on this form is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the supervisor by the 6th of the succeeding month, unless otherwise directed by the supervisor. Form 9-329 (January 1950) 16--25766-9 u. $. GOVrRNMK#T PRINTING OFFICK I/ Form 9-331 (May 1963) SUNDRY NOTICES AND REPORTS ON WELLS (Do not use this form for proposals to drill or to deepen or plug back to a different reservoir, Use "APPLICATION FOR FERMI.T--" for such proposals.) 1. oI,. [_] cas WELL WELL OTHER 2. NAME OF OPERATOR Marathon Oil Company (Operator) 3. ADDRESS OP OPERATOR 731 I Street, Anchorage, Alaska 99501 4. LOCATION OF WELL (Report location clearly and in accordance with any State requirements.* See also space 17 below.) ~t surface 590' south and 1,979' west from NE corner of Sec. 3, T6N, R10W, S.M. ITED STATES sVBm m ' Budget Bureau No. 42-R14 (Other lnstructi~,s on re-- DEPARTMENT Of THE INTERIOR verse side) 5. GEOLOGICAL SURVEY .... A-028118 .., . .... . 8. FARM OR LEASE NAME ... Beaver' Creek 9. WELL NO. 10. FIELD AND POOL, OR WILDCAT .ldca't- : ' 11. SEC., T., R., M., OR BLK. AI~D SURVEY OR AREA ~ Sec. 3, T6N, R10W, S.M. 14. PERMIT NO. 15. ELEVATIONS (Show whether DF, RT, OR, et~) 12. COUNTY OR PA~ISHJ i3. STATE 150' GR (estimated) Kenai Borough Checl¢ Appropriate Box To Indicate Nature o~ Notice, Report, or Other Data NOTICE OF INTENTION TO: 16. TEST WATER SHUT-OFF I I PULL OR ALTER CASING FRACTURE TREAT MULTIPLE COMPLETE SHOOT OR ACIDIZE ABANDON* REPAIR WELL CHANGE PLANS Alaska SUBSEQUENT REPORT OF: WATER SHUT-OFF ~ REPAIRING WELL FRACTURE TREATMENT ALTERING CASING SHOOTING OR ACIDIZING ABANDONMENT* (Other) (NOTE: Report results of multiple completion on Well (Other) Casin~ Pro,ram completion or Recompletion Report and Log form.) 17. DESCRInE PROPOSED OR COMPLETED OPERATIONS (Clearly state all pertinent details, and give pertinent dates, including estimated date of starting any proposed work. If well is directionally drilled, give subsurface locations and measured and true vertical depths for all markers and zones pertl- nent to this work.) * The casing program submitted on the Application for Permit to Drill (dated 6/2/67) this well was designed in anticipation of the apparent high pressure zone pene- trated below 9,000' in Well f~l which bl~w out. Well ~i-A penetrated the 9,000' zone and found it to contain normal bottom hole pressure. No charged zones were encountered while drilling Well ~i-A above 9,000'. It is now our intention to modify the original proposed casing program in the following manner: Size of Hole Size of...Casing .Weight per Foot _Setting Dep~tJ! Quantity of Cement 26" 20" OD Casing 94f/ 250' -~ 650 sacks 17-1/2" 13-3/8" 68¥~ and 72# 2,200' 1,600 sacks 12-1/4" 9-5/8" 40~, 43 5f~, 47f~ 8,800' ~' 1 750 sacks · , · .:; r ~ .. 9 The high pressure blowout prevention equipment as submitted on! '~he attachment to the Application for Permit to Drill will be used. 18. I hereby certify tl~at the foregoing is true and correct · , :",!-R E C E I.V E D .. .:,: JUL 1.. 0'.196:7 ~i"0JVl$1OIN O~. .... 'AINCH.C) RA:GE (~his space for Federal or Stat~ o~ee use) CONDITIONS OF APPROVAL, IP ANY: TITLE_Actg. Dist. Operations Mgr. '~)A~E i i 7/7/67 *See Instructions on Reverse Side '~:/.:" :' /'~:!! ?" :i./':.. Well No, Be,ve~ 0reek ~;2 Lease Nc,~ Aneho~ ~ 028118 ' - - ?:2¥.,' ". :: ' , ' , · '. · . "'L,..' '.~..~: l~:?~'~?~':~J:-?. '.'1.' Oom~liaa, e wi:h ~ederal Oi~ and Gas Opera,,n, Re~la,~ons. ..' '~- J??:~:.?~:;:?~?F:~:v':: . {'..' Regional Oil & Gas Supervisor. ..,. ' · . . ' . .'.'-"'{ .J::~::i~:::::::::::::::::::::~.~:.:' ::"."- ':' ' ' . . ' ' ' . ' · ': - ' ' ·. ' ' ' . ' ..,- j~i-:.~{~t?:}~':;:...:' '/.' and 'Should show name of operato%-, lease Serial nur~ber, w~ll name and "":~.. ~ .~, .~, · %, ,' ...... .,. , . . ., . , . ~x-:~:':,:::.:x. - . _location by ~ seu~mon~ to~nmp anu range. ..- l:?J/,¥'.::': ..~'-- / · ':. "' ' ' - ' -,, J':{q~-:~'::.'~":' :4, The data ac:ual drilling is started shall be repot:ed'promptly to the ' . j%~?:../::~: .:.~.~ Regional Oil a Gas Supe~isor on' form 9-331 "Sundry No~ica.& Reports ,.' ' ' !--.'~ :':.¥ _-:.. ~: .._.,,.:..` '.-,., ~.6. install, adequate ~lowout p=even~zon equipment and ~intai,n in ~0od , '. · ::.:;::' :.'-~ "~:.~'.'." ":.?'~':';','~::?'-;"~ }'' '.-. ~ openin~ and clo~in~ and agains~ pressure. ' .' · . .?:': ~:.':~ · , ".~' ..;T:'~".'~:'.'_-:" . ~ '". ~ '. ' ,' '~ . . . ' ;::: ~.-.-- .~:~.;::.?. :..,:.. ~.-.L~ss~ s Monthly R~port' of Op~r~tmous (form 9-329).covurin~ all o-o~ra~Ions '.'"."'" '..- ::~ .~ .- ,::,-.:~,,,,:-.:,..;., .-. ,... and prouuc~mon on ~h~s lease should oe submztted mn duplicate prior to : ~-~.~.n::~,.._:. ~?~....:::--?:';~]:...?.:~?'..".-(.. ~he tenth of the followin~ month.' [See' section 221 60 ~f :~,,-~--~: n: ~ ~- ' "': .... ::: ~' J d': ':~ '.:',.:':'/: '- B. Final' sf~'oE e:ee~1e~l I~ "~d 1~ r,. , ~ ~ ~ , ~... · ' "' :,-, : ~:..:,,..,~,,,.:,...,. .... ,.: ... P . - ( ) . ~ holoomo ~mu~ io~ o, eh,rose ' -. . ...:,...~:....:.:... ,..: .?. ~. _..: uaua, mnclud.no o~n~ lo~s ~un~ dmrec~lonal su~eys, core descriptions -: :_~?~:?~?;:./,'.'.'~,""~:.':'.:_~ . }'. a~d .analysis, formation tests and sirmiar infornm:ion shall be sub- ': ', .}...~ .., ': :.~..: ~-::. :: .::._.... ~:.;....: ~ .,.. ~,a~ mn sz~gle' copzes.. The above logs and suz~eys shall be'sub~i~ted ~ ,x....' ':..:.u...'. ~'. as Soon as the:reco,-ds are available. Ot'~ ~.:- .... ~ --,.,,<~ ,~ · .:~ ~:}'., ~',,?/.;.' .:.':~.~.. .': mi~'~ed snail be includad ,in or submi~'~ed wi~h ~he W~ll Comple'~ion ile~ort -- ~?':, ' ' :-' ':.'.-, .: : '..: ..:;and Log,. form 9~330. - . ~ - . ] ~ 9. :':'Drii!ing'eqUipment sh~ll no~ be remoged from any suspandud drilling well · ... . -~;?.:.:L;/:-,,,t;.' ' u..,-,.' wi~hou~ firs=, securing the ~i~=en consent of ~he Supervisor. ' .... - ...'.: :. :-:;: ·: "'. .... :':.::,~ :.(:/:}'~.',.; '}:};.::-~ O~l.and Gas ~-~w~Jor, Alaska flea,on...'- :<.{..'.',' ....., ::. . :. : :::.-.., ,,.::: :. :. ::.:':':'.:,: : ?::~,(,,, ... , . . . ,..: ...,..:......' . ' ;":" '"" A' '' "" ' ' ]'' ' ...... "- '-' ~e . ., ?' :': -'-'?:':: ~ :4 " ~ -.~~a--~~~ , ' ...:..7:.:;.' '-_.--" ~ .~ . ... ..:..: ...:.: ,~ed-ona~ ull a Gas oup~rvlsor ':.~'. , - ~- 911, e~,,,:<-- ,-. ~, ~, . :- ~, .: .: ,~...:.. . ~. .~__._r,~__. ..... . ., ..:.::::.:.-,-.. ~ 9yy-~_.~ ~,~x ~,~u mua~u~,~ .. ,:, · -.,:. :u. ~. ~=~o~=~& ~urve~ ' - ' :' ....' . ' · ' ~ E '='"e~ .... "' .... .., Y ....... :... . , S ,__~ . . ... .;.:. . . "'" '"'' ' 'O '" '' ' " ' '" ~' ' ' " : ' "':' :..,~.,-',.uP...~ ~ox 259 ...... ". '.' '.".- ';" '~:::::":::' ."-"-.': Teleohones: · · . ' '.,', . ~";.~ :";. ..-.',: :-"'~- .... ' ..· . .' . ', '. ';'. : ': : v '- .',' "' J!.:';' '..'.-.:.'- '.: i '.' ',..' .:.' ' --. --[ .... '...; '..-{-...''- ': 'is :: -' . ' . '' ; 'i." "-.' "--. "' ' '.., / ;-.. [1 ~: ~-::...:.f .. . '. · ,.'..:..:.:.. .. . ...- , ,.:. '.... ,, .... .' . . .. ....~ ,~ ... ,. '. ;' ' ~ · . ' ":;,"~l"' . :,[ ...... ;',..:" ,', '""t'". ........ .'""":,"i ':'"" "" ' 2 - ·" f- " ?;;J:'¥?':','-.;;, ,':.q:'. ;. -,[.'.::".'q-:', " ..;'5'.::>:./..?~ ' :.','.-'.~"::'"h'.L-:g.::-';"':;':-'..-~i'd}:.:', i.~.C.: ' .,' :.'is .:.; ~[ ¢' ,'/':.'~,'.?:'J~3.'/.~.'.":.>..' 5.': .' : '. ' ' '; }:":"". '. '- ~ .;'irt. -' .... [" .'." l'"/ 'l- 'i:.2.; ..:p.~. . ( "--. ' L ::'i'~.~.' 6 -', '- '-"';.-" ." ' "'<' : '~' ',:,4....: .'.. ~..t: ~'.: · . ' · . : - . ~cO~V[ "- .... '"" :' ~: '"x .... ' ...... ..~. ~ .:,,.. .... ~co~v~,.~., ,: .;:., ..,:',.. .., ~': ...... :., ...... ::.. ,- .,. . -. ~eO~ · ~% ...~%:~ ...... :'-s~, -- ............. DIVISION" - ~ MINES &MI~" ' ' ~O~GE for your V=ry ~=uly Enclomu~e Thomas I~. Marshall~ Jr. Petrole~ $~ervfaor .! CORRECTED APP,I~-~TION - REPLACES FORM 9-331C file~/",¢8167 Form P--1 ' ' ' ' ' " · .~- ..: .. -.- ..... /. .... .. . . ~.. s~iT r~ ~r~..,^~. '" ,:: -:,. :~::.~ ,:' ,,-,: .... - ~ ~ -~a' ' ....': ":-" -:' (Ot~er tn~truetlou~ on" '" " ~fective: July :I, >..% .~...:-: , .. ... ~ . . . :., .... , . ~e~se,14,) . " . . . _:. · . ; . :.. . . . ,. -.~: ~,... ~:,. -.,.- -. ,: ,:. ~.: .:.. _ . . . ., =-. . . ; ~....: . . - ~ APPLICATION FOR PERMIT T~.,D~ DEEPEN, OR PLUG BACK - "' "'""""' .~,o.,,=.. "DRILL· ~ '- . ...... .- 'DEEPEN ~ PLUG BACK ~"'. ~' '~'~ "~'"" ' : '"' ' "~' :: ...... g ~' '" ' ~-: o,~ ~ ~. ~ ....................... ~ ~L~,~, -s. ~ o~ ~ ~'~ ,: . :. . -- · .... : ' .... ' .......... ' ......... : "' Beaver Creek .~.. ,.: '~ ~g~s~ o~'o~rg.~og ............ - .. - . .: ..-.- .- ..... ~ ~oc~o~ o~ w~ (~epo~ loc~ttoa clearly and tn accordance wi~ any S~te r~ulrement~.*) ' ' ' At surface ' ~,9~ 'WeSt from NE corner of Sec. 3,'. ~s~c.,r.,,., ~.,oa ~,,x ..... -. · 5.90' south and l: ~ "~' :., .,- Wildcat ' ' " .... - T6N, R1.0W, S~M. ~' - ........... .:.:... *~v ~,:~=, o~ [~ i~.> - At proposed Prod. ~one . i~,?:: : Same (vertical. hole) ..... " ' Sec 3,-T6N, R!0W, S.M. , . ?~.:. 14, ~z~amc~ ~N ~IL~s a~v DI~C~IO~ ~ao~ ~zaam~ ~ow~ oa ~os~ o~le~* :,j~::~' 12. B. OROUGH s~ J 13.. I1-1/2 niles NE from Kenaf, AlaSka, Pos~ Office . Kenat~ ·Alaska (Al~o to nearest drl~, unit line, if any) · o ~a~rs~ w~, ~n,u~'o, co~o, Fir ell o~ ~n~ ~, ~ ~am' ~, ~. on thi lease s "!~000" 150'_iestimated_) GR .. TO THII~ WI~LL 160 20. ROTARY OR r~pi~3~ v · ~:- PROPOSED CASING AND, CEMENTING PROGRAM 'tllZ~ OF CA~ING /:- WE!G.HT PER FO0~ j ~TTIN~ D~PTH s, '7-518" OD 33.71~ & 29'741~' - 14,000' . 6~5/8" *5" OD liner 18.0(] 16,000' ~UANTIT~'OF CEMEN~ 650 SX -3,200 SX '800 SX ' 220' SX _ * 5" OD liner and cement will be 'required only. if commercial production is' found below 14,000' '' Plan t° drill. ai'Vertical h01e at this:,'!o~ation. '"'"' "':'" "': ':" · .Refer to attachment for drilling program and description of blowout Prevention equipment. · .....:.' :-.: , , * , ', , , ,- ._ · .' ' ,: -., . . · ~m AnOV~ RPAC~ O~SC~ ~O~'OS~ ~aOO~A~: ~ proposal i~ to d~peu or plug back, give data on present productive zdne and p~sed new productive zone. If pro.sat Is to drill or deepen direetlonally, give pertinent data on subsu~ace locations and measured and true vertical depthS. Give blowout preventer program, ~ any. ? - 24. I hereby certify that the Foregoin~-i~--~?~e and correct,,. 3_. ~,~~_Dist. Operations M~r. 6/12f67 _-_3J::Tf_ "" -- (This space -for Federal or S~te o~ce use) COHDITION,~ O.P- APPROVAL, -:':' *See tn~..~c~'~ons On Rever~e Side .: :: RE-C E IVE D JUN 141967 ATTACHHENT BEAVER CREEK WELL NO. 2 U.S.G.S. Form 9-331C Drilling Pro,ram It:is proposed to drill a vertical hole at this surface location to test the pri- mary objective sands in the Hemlock and Cretaceous zones to an approximate total depth of-16,000' in pre-Tertiary Mesozoic rock. A 12-1/4" hole will be drilled to a depth of apProximately 250', hole opened to '17-1/2", hole opened to 26", and 20" OD casing run to 250'. The 20" casing will be cemented with approximately 650 SX ini~order to circulate .cement to surface. A 20" blowout preventer will be. installed before drilling out of the 20" casing. A 15" hole will then be drilled to a depth of approximately 2,200', hole opened to 22", and 16" OD casing run to 2,200'. The 16" OD casing will be cemented with approximately 3,100 SX in order to circulate cement to surface. A 16" 3,000 psi casinghead and 16" 5,000 psi.blowout preventer will be installed before drilling out of the 16" casing. Mud weight will be maintained at approximately 9.6-10.0#/ gallon while drilling'from surface to 2,200'. -. A 14-3/4" hole will be drilled to approximately 8,800' using a mud weight of 10.0#- 10.8#/gallon from 2,200' to 5,000', and a weight of 10.8-11.0#/gallon from 5,000' to 8,800'. Before running 10-3/4" casing, it is planned to perforate the 16" .casing below 2,000' for later use in disposing of waste water_and mud by pumping into the annulus between the 16" and 10-3/4".casings. The 10-3/4" casing will be run to approximately 8,800' after running 1ES, Sonic, dipmeter, compensated formation density, and proximity-microlog caliper logs. -The 10-3/4" casing will be cemented with approximately 3,200 SX in order to bring the top of the cement behind the 10-3/4" casing to approximately 2,500'. A 16" 3,000 psi by 10" 5,000 psi casinghead spool will then be installed and 13-5/8" 5,000 psi .blowout preventers installed be- fore drilling out below the 10-3/4" casing. Mud weight will be increased to 13.5#- 14.0#/gallon before drilling the 10-3/4" casing shoe. A 9-1/2" hole' will be drilled from 8,800' to aPproximately'14,000', logs. run and 7-5/8" casing will be run before penetrating tH-e Hemlock zone. The 7-5/8" casing will be cemented with approximately 800 SX cement in order to bring the top of the cement behind the 7-5/8" casing to at least 8,800'. A 10" 5,000 psi x 10" 5,000 psi casinghead spool, will then be installed and 10" 5,000 psi blowout preventers installed. Mud weight will be decreased to approximately 10,5#/gallon before drilling the 7-5/8" casing shoe in order to prevent damage to the Hemlock formation and prevent lost circulation. A 6-5/8" hole will then be drilled to total depth, logs run, and if prOductive zones 5" OD Hydril flush Joint liner will be are encountered below the 7-5/8" casing shoe, set through all possible producihg zones. '~'::::'20'_.. - ,000# single gate*PluS 20i' ' 2,000# Hydril', outlets-.on mud spool .and 2 relief lines .while drilling/to 2,200' 2. ) 1'6" - 5,O00d double gate pl:us '16':{:'- 5,O00~t.'Hy~(i ~ith 4"- 5,00011 -. flanged outlets on mud upo°l :hnd:~<4'' flanged 5,000~ choke manifold. ..and ~11 line ~hile drilling Co-8;800'.~-'.-~ "13-5/8".-' 5,000# double' kate plus 13-5/8'.'.'~"5'~O00ff':'H~ti'i-tth 6" '5,0005t flanged outlets on mud sPool with 4"'"~ 5,000~ flanged.,choke manifold and kill line while drilling'to '14',000'. I0" - 5,000~ d°uble gate plu, 10,-~.5,000# -~ and kill line while drilling to-~o~al depth. 'a' &- :e 9: e: ,,.,, . . ..(: . ':--},.;" :: "' ':-5~' ~ 7''~ .:'. ','- ' .-: ' ".'.: :"_':'.":-':F. ":" ~" ~ .,; [' /. "~:;U"-'.'. ' ' :' '. :.' . ' -':. ,'" ,-~ r:'" -' ' ';':: ,: ,. ,.','., ' "4'~".'/:.'..~,-r.- .7-L~.: ; . ~- '-- LY ':j:--:"~ ,-" ' :' ~ · , ~ ':' · ' . .: '-.;'xN :'." ' :: . ',:..., :(~')'" ' .'"':::" : '"' '" ':' ' :"' ' :,~'--. ' '.:- . '' ~-' '',:"::4- "-::. ' : , .- '. '. '::- -,,~ r .~.p ~ ...~-.:. ~.: : : ; _ ,- -.:: ,.' ,...': . , .. :, . .:' ..--' El: ~':'- ~' ~?' :"~':"-~ ~ '~??:3~;~:~: :' '.: :,:-'~,',:' ~.'..:(,,.::~ ::;,.:: ~ ';;',:~?'~:~..;,'~:., ,.-~ BEAVER- CREEK NO.2 L LOCI~TION _ . RE-CE-IVED JUN :! ~. 1967 DIVISION OF MINES & MINERAL3 ANCHORAGE AEATHON OIL COMPANY OPE RATOR .BEAVER C'R E E_K NO. 59.0 1 THE A S KA ~ - suRVEYED` BY 'Y S, McLANE~ R.L.S. Dote June 6~ 19-67 ~or~as ~l. ~rskall, Jr. FORM : I'60M 1/67 M[MOP-ANDUM State of A~as~a FROM: DATE : SUBJECT~ · FORM SA - lB !.-b0M IJ~? MEMORANDUM TO: J--. FROM: .~tate oJ Alaska DATE : SUBJECT: Form P I ..... STATE OF ALASKA OIL AND GAS ~CONSERVATION COMMITTEE --.- APT. #50-133-20021 SUBMIT IN TRI ~ATE* Effective; July 1, 1.964 (Other lnstructic,~ on reverse side) APPEICA~TIO'N- FOR~-PERMIT T'O D,RIEL,-DEEPEN, ~OR PLUG BACK ..... DEEPEN~I'l -PLUG BACK I-I . - SINGLE ' [~ MULTIPLE ~_~ OTHER ZONE ZONE ,a. T,P~,O~W0R.~... DRILL b. TYPE O]~'~E~L -' OI~ WELL ~ OAS ~ WELL 2. NAM~ OF O~RATOR ~ ..... Marathon 0t~ Company ~ ADDRESS OF'OPERAToR .... ; ~- '~" - . . "Anchor. age ,.. :Alaska .,9.9501 731 I Street, " ..... "'" ~'" ". _ 4. ~ocA~zON~,OP~ WELL (Report location clearly and in ~cc0rdance with any State requirements.* ) At sU ~fi/~~'' :~ ..... ....... ' ...... 700' S and 2,000'. W from NE comer of Sec 3, T6N, R10WSH At proposed prod. zone 14. DISTANCE IN MILE8 AND DIRECTION FROM NEAREST TOWN OR POST OFFICEs 11.5 miles Northeast from Kenai, Alaska, Post Office 10. DIBTANCJ 'ROM PROPOSED* 16. NO. OF ACRES IN LEASE LOCATION TO NEAREST PROPERT, Ga ~s~ ~x~, ,,. 700 ' 2,560 (Also to nearest drip. unit line, if any) iS. DISTANCE FROM PROPOSED LOCA~ION* First well 19. PROPOSED DEPTH TO NEAREST WELL, DRILLING, COMPLETED, o~ ~ ~, o~ ~ms ~, n. on this lease 16,000 ' VD 5. LEASE DESIGNATION AND SERIAL NO. Fed. Anch. 028118 6. IF INDIAN, ALLOTTEE OR TRIBE NAME 7. UNIT AGREEMENT NAME 8. FARM OR LEASE NAME Beaver Creek ' 9..WELL NO. 2 'i0. FIELD AND POOL, OR WILDCAT Wilcat 11. SEC., T., a., M., OR BLK. AND S~;R~E, o~ ~s~^ Sec 3, T6N, R10W SM 12. BDROUGH sHJ 13. S~ATE ~nai Penin.I Alaska 17. NO. OF ACRES ASSIONED TO THIS WELL 160 20. ROTARY OR CABLE TOOLS Rotary 21. ELEVATIONS (Show whether DF, RT, GR, etc.) J 22.' APPROx. DATE WORK WILL STARTs 150 ' ground [ 6/10/67 23. PROPOSED CASING AND CEMENTING PROGRAM SIZE OF HOLE SIZE OF CASING WEIGHT PER FOOT SETTING DEPTH 26" 20" OD 94 22" 16" OD 84.75 55.5, 51 250' -- 2,000' 15" 10-3/4" 8,500' 9-1/2" 7-5/8" 33.7, 29° 7 14,000 ' 6-5/8" 5" liner 18 16,000' QUANTITY OF CEMEN~ 470 sacks +'2~% excess '3,100 sacks + 2~% excess 5,250 sacks + 2)% excess 1,350 sacks + 25% excess 260 sacks + 25% excess IN ABOVE SPACE DESCRIBE PROPOEED PROGRAM-' If proposal is to deepen or plug back, give data on present productive zone and proposed new productive zone. If proposal is to drill or deepen directionally, give pertinent data on subsurface locations and measured and true vertical depths. Give blowout preventer program, if any. 24. I hereb~Ty ~rti,,fy~ that t~is True and correct. Dr41lin~ fiupmrlnta~dmnt DATE 6/8/67 (This space for Federal or State office use) PERMIT NO. 6 7 - z-c,,, APPROVAL DATE THOMAS:' ~, MARSHALL, JR, TITLE *See Instructions On Reverse Side RECEIVED DIVISION OF- MINES & MtNERAI~ ANC.~ORAGE Operator Marathon Oil Co. Lease NO. A-028118 or Owner Beaver Creek kx~ ~e Date' 1-26-70 Sec ..... 3 State of Alaska Department of Natural Resources DIVISION OF M~NES AigD ~ELNERALS Petroleum Branch T. 6 N R. 10 W INDIVIDUAL WELL RECORD S.. Meridian -¥ Permit No. 67-26 Issued 6-9-67 Location (Surface) 590' FNL & 1979 FEL Sec. 3 Loc. (Bottom) Well No, 2 Area E. of Kenai Spud Dmte~_~513-67 Drilling ceased 11-9-67 S u sp ended Ab an do ne d Completed (F-~'~-~ 52-26~67 __ IP B/D, Grav API. Cut_ + Gas 7000 - MC~, Bean_ ~ /64_ _~.~-:.~CP psi, TP zlS, 0Q .... psi Casing; Size Depth Sx Cmt perf~_!5,.356'-15386%!5,285,~I~g~:; DC 15,4.10' 20"-94~/ 280' 525 15 ,15 8-1..5~ 248 ' DST ~/]. ' ~ .... ~--'r~,*' -il ............"i ........ , ....... . .. , 13 3/8"-_22.13~ 2onn ,~ ,~942 .-62,. ;14964 -74 ~ 14,770'-14~265 50,,,sx. ~ !14,990'-15,020' ;15033'-58' ; 8,700'-8,345' 125 sx. 9 5/8"-40~;&47~/ 8835' 1370 I15,063'.-73%,15,080'-t00', B.P. 5290' ; -- iDST. 7"lnr. f 9~/&32~/ 8594'-15439' 650 15,452'-537'; 15,560'-85' 5,229 -44 ;(5~324 ~44 (mn error) _5'~' lnr_. !5_415'-15697' .,41 5~75'-5220'~Reperf.5!55'-75'~. ~EO~%C FORMATIONS PRODUCTIVE HORIZONS Surface ~owest Tested Name Depth Contents Total Depth ~ 15,697_ _ Elevation 150' Grd. Est - WELL STATUS Year Jan Feb Mar Apr May June July Aug Sept Oct Nov Dec DST. f/! 1! h,2~9', 8 bbls w.c. 5 bbls muddy (lo__ad)water; 45 bbls 33°API oil Dst. ~2 26!~ hrs. gas to surf. 1 hr. 25 min. Recov. ~7 bbls (100Q') W.C. 3 bbls mud & i38 bbts .w.?y% .... 35~ APl oit. Dst. f;3 Rec. W.C.(2500), 720' ,mud, i125~' si. gas-cut salt waterAscum of oil mn' 3.z~" d.p. Dst. f/4 withpagk, ers 5~016'&14,8!2' made some gas. Rec,. 25 bbls ~ater & 5.bbls o.i! Gas lift tests of Hemlock produced 5 to 32 bbls oil 33ol© - more mud & water than oil Remark s: Contractor: Coastal Drilling Co. J 8ZOeZO-V 3 S 0 o~