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Home My WebLink About168-062Hilcorp Alaska, LLC Post office sox 244027 Anchorage, AK 99524-4027 �Al/� P 2�� 3800 Centerpoint Drive k Suite 100 Anchorage, AK 99503 Phone: 907/777-8300 April 30, 2013 Fax: 907/777-8301 Thor Cutler (mailstop OCE -127; 12th floor) UIC Manager, Groundwater Protection Unit U.S. Environmental Protection Agency 1200 Sixth Avenue, OCE -127 Seattle, WA 98101 Re: Cost Estimate and Financial Assurance Underground Injection Control Permit: Class I Permit Number AK -1 1006-A Dear Mrutler: In accordance with Part I.F.4.b of Underground Injection Control (UIC) Permit Number AK -11006-A, Hilcorp Alaska, LLC (Hilcorp) is submitting a cost estimate and proof of financial responsibility for plugging and abandonment (P&A) of the Class I well designated as Dolly Varden Well D-9RD (API # 507332013100). • The cost estimate is $1,500,000 for the well P&A. • A Surety Performance Bond covering the cost of the well P&A is attached. If you have any questions, please direct them to Gretchen Stoddard at (907) 777-8343 or via e-mail at gstoddard(aD-hilcorp.com Sincerely, HILCORP ALASKA, LLC /i L ( , illiam G. Britt, r. Environmental Manager cc: Mark Bentley„ ADEC Cathy Foerster, AOGCC Attachment 1 Surety Bond Documentation SURETY PERFORMANCE BOND U.S. Environmental Protection Agency Underground Injection Control Financial Responsibility Requirement BOND COVERS THE PLUGGING OF INJECTION WELLS Date bond executed: November 15, 2011 Effective date: November 15, 2011 Principal: Hilcorp Alaska, LLC (Legal name of owner or operator) 3800 Centerpolnt, Anchorage, AK 99503 (Business address of owner or operator) Type of organization: Limited Liability Company (Individual, joint venture, partnership, or corporation) State of incorporation: Delaware Surety(ies): Argonaut Insurance Company (Name) 225 W. Washington, 6th Floor, Chicago, IL 60606 (Business Address) EPA identification number, name, address, and plugging and abandonment amounts) for each injection well guaranteed by this bond. (Indicate plugging and abandonment amounts for each well. Attach separate list if necessary.) Injection Well Information ADL 18729 D-9RD API#507332013'100 Total penal sum of bond: $ $2,600,000.00 Surety's bond number: SUR0015259 Plugging & Abandonment Amount $1,500,000.00 - Well P&A $1,000,000.00 - Facility/ Line Removal KNOW ALL PERSONS BY THESE PRESENTS, That we, the Principal and Surety(ies) hereto are firmly bound to the U.S. Environmental Protection Agency (hereinafter called EPA), in the above penal sum for the payment of which we bind ourselves, our heirs, executors, administrators, successors, and assigns jointly and severally; provided that, where the Surety(ies) are corporations acting; as co -sureties, we, the Sureties, bind ourselves in such sum "jointly and severally" only for the purpose of allowing a joint action or actions against any or all of us, and for all other purposes each Surety binds itself, jointly and severally with the Principal, for the payment of such sum only as is set forth opposite the name of such Surety, but if no limit of liability is indicated, the limit of liability shall be the full amount of the penal sum. WHEREAS said Principal is required, under the Underground Injection Control Regulations, as amended, to have a permit or comply with provisions to operate under rule for each injection well identified above, find WHEREAS said Principal is required to provide financial assurance for plugging and abandonment as a condition of the permit or approval to operate under rule, and WHEREAS said Principal shall establish a standby trust fund as is required when a surety bond is used to provide such financial assurance; NOW, THEREFORE, the conditions of this obligation are such that if the Principal shall faithfully perform plugging and abandonment, whenever required to do so, of each injection well for which this bond guarantees plugging and abandonment, in accordance with the plugging and abandonment plan and other requirements of the permit or provisions for operating under rule and other requirements of the permit or provisions for operating under rule as may be amended, pursuant to all applicable laws, statutes, rules and regulations, as such laws, statutes, rules, and regulations may be amended, Or, if the Principal shall provide alternate financial assurance as specified in Subpart F of 40 CFR 144, and obtain the EPA Regional Administrator's written approval of such assurance, within 90 days after the date of notice of cancellation is received by both the Principal and the EPA Regional Administrator(s) from the Surety(ies), then this obligation shall be mill and void. Otherwise it is to remain in full force and effect. The Surety(ies) shall become liable on this bond obligation only when the Principal has failed to fulfill the conditions described above. Upon notification by an EPA Regional Administrator that the Principal has been found in violation of the plugging and abandonment requirements of 40 CFR 144, for an injection well which this bond guarantees performances of plugging and abandonment, the Surety(ies) shall either perform plugging and abandonment in accordance with the plugging and abandonment plan and other permit requirements or provisions for operating under rule and other requirements or place the amount for plugging and abandonment into standby trust find as directed by the EPA Regional Administrator. Upon notification by an EPA Regional Administrator that the Principal has failed to provide alternate financial assurance as specified in Subpart F of 40 CFR 144, and obtain written approval of such assurance from the EPA Regional Administrator(s) during the 90 days following receipt by beth the Principal and the EPA Regional Administrator(s) of a notice of cancellation of the bond, the Surety(ies) shall place funds in the amount guaranteed for the injection well(s) into the standby trust fund as directed bythe EPA Regional Administrator, The Surety(ies) hereby waive(s) notification of amendments to plugging and abandonment plans, permits, applicable laws, statutes, rules, and regulations and agrees that no such amendment shall in any way alleviate its (their) obligation on this bond. The liability of the Surety(ies) shall not be discharged by any payment or succession of payments hereunder, unless and until such payment or payments shall amount in the aggregate to the penal sum of the bond, but in no event shall the obligation of the Surety(ies) here under exceed the amount of said penal sum. The Surety(ies) may cancel the bond by sending notice by certified mail to the owner or operator and to the EPA Regional Administrator(s) for the Region(s) in which the injection well(s) is (are) located, provided, however, that cancellation shall not occur during the 120 days beginning on the date of receipt of the notice of cancellation by both the Principal and the EPA Regional Administrator(s), as evidenced by the return receipts. The Principal may terminate this bond by sending written notice to the Surety(ies); provided, however, that no such notice shall become effective until the Surety(ies) receive(s) written authorization for termination of the bond by the EPA Regional Administrator(s) of the EPA Region(s) in which the bonded injection well(s) is (are) located. (The following paragraph is an optional rider that may be included but is not required.) Principal and Surety(ies) hereby agree to adjust the penal sum of the bond yearly so that it guarantees a new plugging and abandonment amount, provided that the penal sum does not increase by more than 20% in any one year, and no decrease in the penal sum takes place without the written permission of the EPA Regional Administrator(s). In WITNESS WHEREOF, The Principal and Surety(ies) have executed this Performance Bond and have affixed their seals on the date set forth above. The persons whose signature appear below hereby certify that they are authorized to execute this surety bond on behalf of the Principal and Surety(ies) and that the wording on this surety bond is identical to the wording specified in 40 CFR 144.70(c) as such regulation was constituted on the date this bond was executed. PRINCIPAL: Hilcorp Alaska, LLC CORPORATE SURETY(IES): Argonaut Insurance Company (Name) (Name) 3800 Centerpoint, Anchorage, AK 990503 225 W. Washington, 6th FI (Address) (Addre (Signature(s)) na ►re(s ` (ohn A. Martinez (Name(s)) (Name(s)) V i + L r () Attorney -in -Fact (Title(s)) (Title(s)) Corporate Seal Corporate Seal Delaware Illinois State of Incorporation $ 37, 500.00 Bond Premium , Chicago, IL 60606 State of Incorporation $ 2,500,000.00 Liability Limit (For every co -surety, provide signature(s), corporate seal, and other information in the same manner as for Surety above.) k ct-r-c - c) 4 Z Hilcorp Alaska, LLC C Post Office Box 244027 AAnchorage, AK 99524-4027 MAY �'• �' 3800 Centerpoint Drive Suite 100 ,r• ,r,'.. p"z. !"',.F"• Anchorage, AK 99503 %1 Phone: 907/777-8300 April 30, 2013 Fax: 907/777-8301 UIC Manager, Groundwater Protection Unit Thor Cutler (mailstop OCE -127; 12th floor) U.S. Environmental Protection Agency 1200 Sixth Avenue, OCE -127 SCWK Seattle, WA 98101 Re: Underground Injection Control Permit: Class I Permit Number AK -1 1006-A State of Alaska Permit Number 201ODB0001-0002 Cook Inlet, Alaska, Trading Bay Unit, Dolly Varden Platform Well D-91RD 1st Quarter 2013 Injection Well Monitoring Report Dear UIC Manager: Hilcorp Alaska, LLC operates the Dolly Varden Platform that injects regulated fluids under Underground Injection Control (UIC) Permit: Class I Permit Number AK -11006-A. Pursuant to condition Part 2, E.1 of the Permit, Hilcorp is hereby submitting the first quarter (January, February, March) 2013 Injection Well Monitoring Report far the Dolly Varden Platform Well D-9RD. The well is currently not injecting waste. No fluids were injected in this reporting period. Fluids will not be injected except for diagnostic and maintenance activities until permit conditions to resume activity are met. No wastes were brought to the Dolly Varden Platform from other facilities for the purpose of injection in Well D-91RD during this period. An electronic copy of the daily monitoring data is included as Attachment 1 along with data comments and graph of daily injection pressure and rates. Ongoing diagnostic and maintenance activities at this well were documented in a letter from Hilcorp to USEPA on April 16, 2013. Downhole pressure anomalies were identified during well operation on October 21, 2012. The well has not operated since this time except for testing to determine the source of the problem and to determine the ways to fix the pressure and downhole problems. Consistent with the approval to commence Class I injection activities by the EPA dated May 13, 2011, this letter certifies the Injection Well Monitoring Report attached to this letter. If you have any questions, please direct them to Gretchen Stoddard at (907)777-8343 or via e-mail at gstoddard(D_hilcorp.com. UIC Manager US Environmental Protection Agency March 30, 2013 Page 2 I certify under penalty of law that I have personally examined and am familiar with the information submitted in this document and all attachments and that, based on my inquiry of those individuals immediately responsible for obtaining the information, I believe that the information is true, accurate, and complete. I am aware that there are significant penalties for submitting false information, including the possib0ity of fine and imprisonment. Sincerely, T ORP ALASKA, LLC A. Barnes Senior Vice President Exploration & Production- Alaska gws Attachment: 1st Quarter 2013 Injection Monitoring Well Report cc: Marc Bentley, ADEC Cathy Foerster, AOGCC OMB No. 2040-0042 Approval Expires 12!31/2011 United States Environmental Protection Agency �EPA Washington, DC 20460 � Injection Well Monitoring Report --,2M3 Month Month Month Injection Pressure (PSI) 1. Minimum 2. Average 3. Maximum Jan Feb March 0 0 0 0 0 0 0 0 0 Injection Rate (Gal/Min) 1. Minimum 2. Average 3. Maximum 0 0 0 0 0 0 0 0 0 Annular Pressure (PSI) 1. Minimum 2. Average 3. Maximum 0 0 0 0 0 0 0 0 0 Injection Volume (Gal) 1. Monthly Total 2. Yearly Cumulative 0 0 0 0 0 0 Temperature (F °) 1. Minimum 2. Average 3. Maximum NA NA NA NA NA NA NA NA NA pH 1. Minimum 2. Average 3. Maximum NA NA NA NA NA NA NA NA NA Other Name and Address of Permittee John Barnes 3800 Centerpoint Drive, Anchorage, AK 99503 Permit Number AK -1 1006-A Name and Official Title (Please type or print) John Barnes Senior Vice President, Expoloration and Production Alaska Sign ure �_ Date Signed April 30, 2013 EPA Form 7520-8 (Rev. 12-08) `i .N 3,000 CL to C H fl. 2,000 to M U a 1,000 m a M A cc C D-9RD Daily Injection Graph, 1st Quarter 2013 10/21/12 DV9RD shut in due to pressure anomolies. 1/19 wireline spinner survey to evaluate well problems. 10/22/12 to current; Well shut in. Some diagnostic testing to determine cause of well problems. Zero Injection Rate, Hours on, and Injection Pressures. 3/28 wireline activities to diagnose problem. 0 ' 117 QP CP QN, 7" Casing Press, psi Tubing Press, psi >,lnjection Rate, BPD Hours On 100 90 80 r 70 60 u 50 00 C O L 40 at 20 10 0 D-9RD Daily Injection Values 1st Quarter 2013 Gallons 1st Qtr 2013 Cumulative Injection Volume: 0 2013 Cumulative Injection Volume: 0 Page 1 Tbg Inj. Tbg Inj. Annular Daily Rate Press. Daily Rate Press. Press February (GPM) si(psi) January (GPM) si(psi) Minimum 0 Temp. LF. pH Minimum 0 0 0 NA NA Average 0 0 0 NA NA Maximum 0 0 0 NA NA 0 Gallons Monthly Cumulative Volume: 0 Gallons 1st Qtr 2013 Cumulative Injection Volume: 0 2013 Cumulative Injection Volume: 0 Page 1 Tbg Inj. Annular Annular Daily Rate Press. Press Press. Press February (GPM) si(psi) March Temp. LFJ pH Minimum 0 0 0 NA NA Average 0 0 0 NA NA Maximum 0 0 0 NA NA Maximum Gallons 0 0 NA Monthly Cumulative Volume: 0 Gallons Gallons 1st Qtr 2013 Cumulative Injection Volume: 0 2013 Cumulative Injection Volume: 0 Page 1 Tbg Inj. Annular Daily Rate Press. Press March (GPM) (I)SO LpsjjTemp. ff� pH Minimum 0 0 0 NA NA Average 0 0 0 NA NA Maximum 0 0 0 NA NA Gallons Monthly Cumulative Volume: 0 Gallons 1st Qtr 2013 Cumulative Injection Volume: 0 2013 Cumulative Injection Volume: 0 Page 1 D-9RD Daily Injection Values 1st Quarter 2013 Comments for 1st Quarter 2013 A. 10/21/2012 Pressure anomolies noted at D-09RD and well shut in. B. 10/22/2012 Thor Cutler, EPA and Marc Bentley, ADEC notified of pressure anomolies. Well will remain shut in until agencies notified and cause of problems is identified. D. Late 2012 Additional diagnostic activities performed and documented on 4th quarter 2012 Report. E. 1/19/2013 Wreline spinner survey is not able to identify and fix problem. F. 3/28/2013 Wireline activities are not able to identify and fix problem. Page 2 D-9RD Daily Injection Values 1st Quarter 2013 1/1/2013 0 0 0 0 0 1/2/2013 0 0 0 0 0 1/3/2013 0 0 0 0 0 1/4/2013 0 0 0 0 0 1/5/2013 0 0 0 0 0 1/6/2013 0 0 0 0 0 1/7/2013 0 0 0 0 0 1/8/2013 0 0 0 0 0 1/9/2013 0 0 0 0 0 1/10/2013 0 0 0 0 0 1/11/2013 0 0 0 0 0 1/12/2013 0 0 0 0 0 1/13/2013 0 0 0 0 0 1/14/2013 0 0 0 0 0 1/15/2013 0 0 0 0 0 1/16/2013 0 0 0 0 0 1/17/2013 0 0 0 0 0 1/18/2013 0 0 1 0 0 0 1/19/2013 0 0 0 0 0 1/20/2013 0 0 0 0 0 1/21/2013 0 0 0 0 0 1/22/2013 0 0 0 0 0 1/23/2013 0 0 0 0 0 1/24/2013 0 0 0 0 0 1/25/2013 0 0 1 0 0 0 1/26/2013 0 0 0 0 0 1/27/2013 0 0 0 0 0 1/28/2013 0 0 0 0 0 1/29/2013 0 0 0 0 0 1/30/2013 0 0 1 0 0 0 1/31/2013 0 0 0 0 0 2/1/2013 0 0 0 0 0 2/2/2013 0 0 0 0 0 2/3/2013 0 0 0 0 0 2/4/2013 0 0 0 0 0 2/5/2013 0 0 0 0 0 2/6/2013 0 0 0 0 0 2/7/2013 0 0 0 0 0 2/8/2013 0 0 0 0 0 2/9/2013 0 0 0 0 0 2/10/2013 0 0 0 0 0 2/11/2013 0 0 0 0 0 2/12/2013 0 0 0 0 0 2/13/2013 0 0 0 0 0 2/14/2013 0 0 0 0 0 2/15/2013 0 0 0 0 0 2/16/2013 0 0 0 0 0 Page 1 D-9RD Daily Injection Values 1st Quarter 2013 2/17/2013 0 0 0 0 0 2/18/2013 0 0 0 0 0 2/19/2013 0 0 0 0 0 2/20/2013 0 0 0 0 0 2/21/2013 0 0 1 0 0 0 2/22/2013 0 0 0 0 0 2/23/2013 0 0 0 0 0 2/24/2013 0 0 0 0 0 2/25/2013 0 0 0 0 0 2/26/2013 0 0 0 0 0 2/27/2013 0 0 0 0 0 2/28/2013 0 0 0 0 0 3/1/2013 0 0 0 0 0 3/2/2013 0 0 0 0 0 3/3/2013 0 0 0 0 0 3/4/2013 0 0 0 0 0 3/5/2013 0 0 0 0 0 3/6/2013 0 0 0 0 0 3/7/2013 0 0 0 0 0 3/8/2013 0 0 0 0 0 3/9/2013 0 0 0 0 0 3/10/2013 0 0 0 0 0 3/11/2013 0 0 0 0 0 3/12/2013 0 0 0 0 0 3/13/2013 0 0 0 0 0 3/14/2013 0 0 0 0 0 3/15/2013 0 0 0 0 0 3/16/2013 0 0 0 0 0 3/17/2013 0 0 0 0 0 3/18/2013 0 0 0 0 0 3/19/2013 0 0 0 0 0 3/20/2013 0 0 0 0 0 3/21/2013 0 0 0 0 0 3/22/2013 0 0 0 0 0 3/23/2013 0 0 0 0 0 3/24/2013 0 0 0 0 0 3/25/2013 0 0 0 0 0 3/26/2013 0 0 0 0 0 3/27/2013 0 0 0 0 0 3/28/2013 0 0 0 0 0 3/29/2013 0 0 0 0 0 3/30/2013 0 0 0 1 0 0 3/31/2013 0 0 0 1 0 0 Page 2 ~ -- lc-apfm lOj an95 PLUGGING & LOCATION CLEARANCE REPORT state of Alaska ALASKA OIL & GAS CONSERVATION COMMISSION PTD No. GR - C6Z- I Lease APL /B"72.g "- Memorandum To .File: API No. Well Name Operator Location ( .3 '3 - 2. 0 , "3 t -erð Tra.r1c~r (Bey (1~;-+- .;(. 1Acò-pt q.a-= ì~ D-9 Spud: '1/2.7(68 ~( TD: , -r~ tV, R (B'tO. 5M ./ Abnd Date /2.(2.:0/ A-f Completed . ej 3"O!6S Note casing size, wt, depth, cmt vol, & procedure. Sfc Csq: {.3~Ct(l hl ,j Ii? 2S:-3f bj/2L10Q s-~ r; ./ / r- . £ Long Csg: 9(8 /r.o/!f~..rJ¡7 tv/A tfS> 1/. :?'2..ï'wlr-- r32.~, 2.."- 12.'+8 ( r { ~ , Liner: Perf intervals - tops: lQ!fT!Ç - ,. rl1-fera-d.> - I f I 'IT§; , Review the well file, and comment on plugging, well head status, and lo.cation clearance - provide loc. clear. code. h i ~ .5 7 Zl - $""' l- 8ù Plugs: CI GI-rrl:. 'I;;;. perk wf~ (9 ~ ~ " F? P ~ r.:: [0 D / ~ ~ {--J;..:}18~ - P ('l ,58& LJ :"¿(Z- -Z-u,- - ry ~ 11-.' We!· head cut off: ~ Marker post or plate: .~ Location Clearance: Concùusions: (~~{\ .O~~í' ~~ed R J? CL5. D- RD I D /- . Code 9 Signed ti?j~_ 1~~lN Date ~¡'O~/9~ APR 21.1990 AlaSkA Pi} i Gas Cons.. Commission -';'~~çÞ~\1I .~'., Rr't"'C'\Jr'r' :, C'.~' r\,., " "'_;"'~' i!..y GSB/lew Yours very truly, G~~~U~· b~~ Reg10nal Drilling Manager I have attached surface survey locations of the "Legs" and conductors for the four platforms in the Trading Bay unit as well as the Union Oil-operated Monopod and Granite Point Platforms. I was unable to locate any plats from a registered surveyor but I hope this will meet your needs. Dear Ms. Johnson: Alaska oil & Gas Conservation commission 3001 Porcupine Dr. Anchorage, AK 99504 Attn: Ms. Elaine Johnson Alaska Region April 16, 1990 UNOCALfj c~ Unocal North Americ Oil & Gas Division Unocal Corporation P.O. Box 190247 Anchorage, Alaska 99519-0247 Telephone (907) 276-7600 1'\ /~, ......."::. DOLLY DISTANCE & DIRECTIONS FROM SE CORNER SEC. 6, T8N, R13W CONDUCTOR "Y" COORD. "X" COORD. WELL # FSL FWL LEG IIA-1: 2,490,836.22 . 208.461.20 757.5 1212.0 LAT = 60°48' 28.272" LONG =151°37' 57.620" 1 2,490,836.95 208,454.55 0-27 758. 1 1205.5 2 2,490,840.99 208,456.66 D-28 . 762. 1 1207.4 3 2,490,842.79 208,460.79 0-29 764.0 1211.5 4 2,490,841.51 208,465.11- '0-32 762.9 1215.8 5 ,2,490,837.76 208,467.60 D-40 759.2 1218.4 6 2,490,833.28. 208,467.10 0-41 754.7 1218.0 7 2,490,830.18 208,463.83 0-26 751.5 1'214.8 8 2,490,829.90 208,459.34 0-25 & RO 75T.1 1210.3 9 2,490,832.58 208,455.72 753.7 1206.7 10 2,490,835.56 208,458.66 0-24 & 34A 756.8 1209.5 11 2,490,838.66 208,462.17 0-31 & RO 760.0 1213.0 12 2,490,834.00 208,462.61 0-24A 755.3 1213.5 LEG #A-2: 2,490,835.42 208,381.20 754.7 1132. 1 1 2,490,836.16 208,374.66 0-1 755.3 1125.5 2 2,490,840.19 208,376.67 D-17 759.4 1127.4 3 2,490,842.00 208,380.80 0-11 761.3 1131.5 4 2,490,840.72 208,385.11 D-7 & RO 760. 1 1135.9 5 2,490,836.97 208,387.60 0-9 756.4 1138.5 6 2,490,832.49" 208,387.10 0-19 751.9 1138. 1 7 2,490,829.39 208,383.84 D-23 748.8 11 34 . 9 8 2,490,829.11 208,379.34 D-21 748.4 1130.4 9 2.490,831.78 208,375.72 D-5 & RO 750.9 1126. 7 10 2,490,834.77 208,378.66 0-15 & RO .& 2 754.0 1129.6 11 2,490,837.86 208,382.17 0-3 & RO 757.2 1133.0 12 2,490,833.21 208,382.61 D-13 752.5 1133.6 LEG #8-1: 2,490,756.22 208,462.00 677.5 1214.8 LAT = 60°48' 27.485" LONG =151°37' 57.564" 1 2,490,755.48 208,468.53 0-8 & RO 677.0 1221.4 2 2,490,751.45 208,466.53 D-6 672.9 12"9.5 3 2,490,749.65 208,462.40 D-14 & RD 671.0 1215.4 4- 2,490,750.92 208,458.08 D-20 672. 1 1 211 ,. 1 5 2,490,754.67 208,455.59 0-16 675.8 1208.5 6 2,490,759.15 208,456.10 0-22 680.3 1208.9 7 2,490,762.25 208,459.36 0-2 & A & RD 683.5 1212.1 8 2,490,762.53 208,463.85 0-4 683.9 1216.5 9 2,490,759.86 208,467.48 0-10 681.3 1220.2 10 2,490,756.87 208,464.53 0-12 & RO 678.3 1217.4 11 .2.490,753.78 208,461.02 0-18 675. 1 1213.9 12 2,490,758.43 208,460.58 0-30 & RD 679.7 . 1213.4 LEG #8-2: 2,490,755.43 208,382.00 674.8 11 34 . 9 (Reserved for Compressors) jo/A.MTM.IB On August 29 t 1986 a repr.esentative of the Commission witnessesd a no-flow test on the subject well verifying that the well is no longerc.apable of unassisted flow of hydrocarbons. The Alaska. Oil and Gas Conservation Connnission hereby authorizes the removal of the subsurfa.ce safety valve from the well. If any subsequent operation restores the well to unassisted flow capability, prompt notification of the Commission and reinstallation of the subsurface safety valve will be required. Si~~erelyu' (j ~...... Æ.. ,;// .....f . c~'v"'^VY~~ {-%v____~l Lonnie C. Smith Commissioner Dear Mr. Loran: Mr. David Loran Operations Superintendant Marathon Oil Company P. O. Box 102380 Anchorage, AK 99510 Re: No-flow Test Marathon Dolly Varden Platform Well TBU D-9 McArthur River Field October 1, 1986 Telecopy No. (907) 276-7542 ;;--: ..--.. I .t ~..... . MEMeRAN~UM State--of Alaska ALASKA or &dJ GAS CONSERVATIDN COMMISS'J.uN TO: c. Ch DATE: September 10, 1986 FILE NO.: D.EWS .50 THRU: Lonnie C. Smith Commissioner TELEPHONE NO.: FROM: Edgar W. Sipple, Jr. Petroleum Inspector SUBJECT: No Flow Tee t Marathon TBU D-9 Dolly Varden Platform McArthur River Field fridª,y, Auest.29, 1986: A no flow test was run on TBU well D-9. This well ·as 63%-90% water content. When the injection gas was shutoff, the well gave out 1 bbl of fluid the first hour of testing with no further increase of fluid. (See attached data.) There was approximately 5 paigof gas venting from the well with no liquids. The well was vented into a 55 gal drum for 6 hours with no liquids. All test data, gas lift chart, separator chart, operator notes of liquids into separator are attached to this report. In summary, I witnessed the no flow on D-9, Marathon Dolly Varden platform. I recommend an approval of no flow status on this well. Attachments )2-001 A(Rev 10-84) LC S/ JI<T / glh , Sinperely, _ (' 1· " (t~/ \ ~>--...;..j , ~,\ J . '\ . ., . ' ./ .. ,_.t, (,.t,... i. _. ~"'"\' ~. I r·,,__.,--'1 _ '-. t.-1....- 'to~nie c. tSlñi.th Commissioner Brief Description of Intention Reparfcrate G-3, C-4 Repcrforate B-1, B-2, B-4 Reperforate a-5, B-1, B-4 Rcperforate Reperforate Perforate B zone Clean out, reperforate' Plug & abandon for sidetrack Pull tubing, rcperforate Squeeze cement to abandon hemlock Chðnge kickoff point Reperforate Revise setting abandon~ent . retainer Repair caGing Perforate 10/1/80 10/1/80 10/1180 10/1/80 11/6/80 2/11/81 6/1/ 81 6/ e / B1 11/25/81 1/20/62 3/18/82 4/21/82 5/24/82 6/30/82 7/14/82 TBUSG-3 K-IPl> TBU D-6RD TBU G-7 TBUS G-2 TBtJG-SRD TBU G- BRD TBD G-23RD TEU A-1lL TaU·J(-4P.D GPS 33-14RD KEO 13-8 TBU D·9 'rBUS C-27 TBUS G-6 Union Date ~ For the following lists of "Notice of Intention To: II Ðundry l~otices and Report on Wells (form 10-403) this office does not have on record the ·Subsequent Report of:ft defining the action taken on the. approved . intention. Please advise this offic:;e by Subsequent Report of the disposition of the intention. Res Subsequent Reports, sundry Notices and Reports on 1-vells (Form 10-403) Union Oil Company of ,California P.O. Box 6247 Anchoraqe, Alaska_,99502 February 16, 1983 . . r\:~ ...~ ..(;. ...-..,. ~i STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION SUNDRY NOTICES AND REPORTS ON WELLS ~"\ r \ :-"\ ~ /(, ~ 1. DRILLING WELL 0 COMPLETED WELL)Q{ OTHER 0 2. Name of Operator Union Oi I Company of Cal ifornia* 3. Address P. O. Box 6247, Anchorage AK 99502 4. Location of Well 7. Permit No. 68-62 8. API Number 50- 733-20131 Dolly Varden Platform, Leg A-2, Cond #5 756.4'FSL, 1138.5'FWL, Sec 6-8N-13W-SM 9. Unit or Lease Name Tradin Ba Unit 10. Well Number 0-9 11. Field and Pool 5. Elevation in feet (indicate KB, OF, etc.) 106'KB MSL 12. 6. Lease Designation and Serial No. McArthur River Field ADL 18129 Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) Perforate 0 Alter Casing 0 Perforations Stimulate 0 Abandon ~ Stimulation Repair Well 0 Change Plans 0 Repairs Made Pull Tubing 0 Other 0 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). (Submit in Duplicate) o Altering Casing o Abandonment o Other o o o o It is our intent to plug and abandon the existing we I I bore and sidetrack a new hole to a location 1300 feet north of its existing bottom hole location. Plug back Hemlock perfs as follows: Benches 3, 4, & 5: Benches 0, 1, & 2: 10,822'-11,153' wi approx 120 sx cmt 10,596'-10,798' wi approx 75 sx cmt. Kick-off plug wil I be laid from 5550'-5850' with approximately 110 sx cmt. RECEIVED JUN - 9 1981 Alaska Oil & Gas Cons C . AnChoragå omn)Ssion *Marathon Oi I Company - Sub-Operator Title DIST DRLG SUPT Date 6/8/81 Approved by Form 10-403 Rev. 7-1-80 ,1'7(fYl~t/P a-bQl1doJIIW)el1f OR1 G ~NAl SIGNED" BY HkRRY W. KIfGJ E' I I I þuf #~f d'J-;///).? r",r<7h<>Þ$ AI/#ou/ /,.r~;;T I t - provød Copy By Order of Returned COMMISSIONER the Commission Date -td 9 fl... 5ubmit "Intentions" in Triplicate sequent Reports" in Duplicate ~. Dear Mr. Hamilton: Union Oil and Gas [,~ion: Western Region Union Oil Company VI California P.O. Box 6247, Anchorage, Alaska 99502 Telephone: (907) 279-7681 unlen January 20, 1976 Mr. Hoyle Hamilton Division of Oil & Gas Sta te of Alaska 3001 Porcupine Drive Anchorage, Alaska 99-502 RE: TBUSJ}-::~(].~-33) TB US ~.::.9~{42-7) \,.. -.-" TBUS D-11 (14-32) TBUS D-25 (11-8) DOLLY VARDEN PLATFORM Enclosed for your approval and in triplicate are the Sundry Notices & Reports on Wells (Form 10-403) for each of the above captioned workovers. sk cc: Marathon Oil Co. Atlantic Richfield Co. Amoco Production Co. Standard Oil Co. Skelly Oil Co. .Phillips Petroleum Co. Mr. Rodney Smith-USGS Very truly yours, dh'!:n~ District Dr 19. Supt. I~.I \! . A. . .-. ,~~.. .. ~.....~ 1 I " I ~,. \ ~ .: -:,. '. . Y¿þ!-; 'îj~'À ~¡ . -', . , " ...'.!....; " ~.- '~I/ . , ! r; r (, .; . '" -. ... . f I I ~ \. 1'- I : . I I ~' I t . ~. " . ' ¡ 1/ i , I' ,--t t'I ~:.., '~ L I 1 ",1. 'J '.'. ",. .\ ' ,. .' , . . I' ' ..'. . . I I . , ¡ .. ~ I \ ! ! ..¿ ~Œa;Œ~,'WfË~ - JA N 2 2 1976 DIVISiON OF OiL AND GAS ANCøOIl~nR . ..... .... '. Form 10-403 REV. 1-10-73 1""""""', Subml t ... ntentlons" In Triplicate & "Subsequent Reports" In Duplicate -... . STATE OF ALASKA 5. API NUMERICAL CODE OIL AND GAS CONSERVATION COMMITTEE 50-133-20131 6. LEASE DESIGNATION AND SERIAL NO. SUNDRY NOTICES AND REPORTS ON WELLS (Do not use this form for proposals to drill or to deepen ADL 18729 Use "APPLICATION FOR PERMIT-" for such proposals.) 1. OIL [] 7. IF INDIAN, ALLOTTEE OR TRIBE NAME GAS 0 WELL WELL. OTHER 2. NAME OF OPERATOR 8. UNIT, FARM OR LEASE NAME Union Oil ComDanv of California * Tradina Bav Unit 3. ADDRESS OF OPERATOR 9. WELL NO. 909 Wes t Ninth Avenue~ Anchoraae. AK . 99501 D-9 (42-7) 4. LOCATION OF WELL 10. FIELD AND POOL, OR WILDCAT At surface McArthur River Hemlock 761.31 N~ 1131.51 E from SW Corner 11. SEC., T., R., M., (BOTTOM HOLE OBJECTIVE) Sec. 6, T8N, R13W, SM Sec. 7, T8N, R13W't SM 13. ELEVATIONS (Show whether DF, RT, GR, etc.) 12. PERMIT NO. RKB 1061 14. Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: TEST WATER SHUT-OFF ~ FRACTURE TREAT SHOOT OR ACIDIZE REPAIR WELL (Other) PULLOR ALTER CASING ~ MULTIPLE COMPLETE ABANDON* CHANGE PLANS WATER SHUT-OFF Ed FRACTURE TREATMENT SHOOTING OR ACIDIZING (Other) REPAI RING WELL ALTERING CASING ABANDONMENT* ~ (NOTE: Report results of multiple completion on Well Completion or Recompletlon 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. 11-09-75 - 11-17-75 Re-perforate Hemlock Zone as fo 11 ows : 10,758' - 10,7681 (101) 4 HPF 2-1/8" Jet, Ba r Gun 10,9521 - 11,0301 (781 ) 4 HPF 2 -1/ 8" Jet, Ba r Gun (881 ) MMCF MMCF Prod. Test BOPD BWPD WC LIFT SEP CSG TBG Before Re-Perf. 60 535 90.0% 1189 3279 1125 psi 110 psi After Re-Perf. 86 1055 92.5% 1571 341 1175 psi 160 psi TITLE Dist. Dr If¡. Sllpt. DATE 1/7.1/7" , , {This s APPROVED BY CONDITIONS OF APPROVAL, IF ANY: TITLE DATE * Marathon Oil Company, Sub-Operator See Instructions On Reverse Side ~ ~ /~ ;i1J l t.....~~ Form No. P--4 REV. 9-~-67 STATE OF ALASKA SUBMIT IN DUPLICATE Oil AND GAS CONSERVATION COMMITIEE MONT'HL YREPORT O'FD·RILLlNG AND WORKOVER OPERATIONS 5. API NU:VIERlCAL CODE 50-133-20131 6. LEASE DESIGNA'I'10N AXD SERIAL NO. ADL 18729 1. 7. IF INDIA~, ALaTTEE OR TRIBE NAME OIL WELL fVl GAB 0 lAJ WELL OTHER 8. UNIT, F AlU1 OR LEASE NAME Tradin Ba Unit 9. WELL NO. 2. NAME OF OPERATOR Surface: 756.4' N, 1138.5' E from SW Corner, Sec. 6, T8N, R13W, SM 11. SEC.. T., R., M.. BOITOM HOLE oBJECTIVE) Sec. 7, T8N, R13W, SM Top of Hemlock: 1980' S, 660' W from NE Corner, Sec. 7, T8N, R13W, SM 12. PERMIT NO. 68-62 13. REPORT TOTAL DEPTH AT END OF MONTH, CHA."<GES IN HOLE SIZE, CASING AND CEMENTING JOBS INCLUDING DEPTH SET AND VOLUMES USED, PERFORATIONS. TESTS AND RESULTS. FISHING JOBS, JUNK IN HOLE AND SIDE-TRACKED HOLE AND ANY OTHER SIGNIFICANT CHANGES IN HO~ CONDITIONS. WORKOVER - Trading Bay Unit D-9, October 1968 10/14 Moved rig from D-11 to D-9; rigged up Otis and ran 3-1/2 Type Q No Go Plug and set plug bottom Q nipple at 10,533'; pulled out and rigged up BJ to tubing head to circulate hole clean with diesel. 10/15 Displaced hole with 740 bb1s diesel followed by 164 bb1s 9.4 1blga1 salt water down tubing; displaced tubing and annulus with fresh water; tested Q plug in nipple at 10,533' to 1000 psi, held OK. Bled pressure to 0, well dead; removed Xmas tree, installed back pressure valve in tubing hanger, nipp1ed up BOP's. Ran landing joint to tubing hanger. Landing joint would only make up four rounds; pulled landing joint threads, showed slight amount of gau1ding; removed BOPs and found back pressure valve not screwed into tubing hanger far enough to permit joint makeup; nipp1ed up BOPs; installed dummy ball valve and tested BOPs to 2500 psi, held OK. Pulled tubing hanger and seal assembly from AGT packer; began pulling tubing. 10/16 Continued pulling tubing; circulating sleeve was closed and had pieces of rubber in ports; sleeve was not washed out; all seal nipple was in good condition; mark on bottom of seal nipple showed it had set on top of packer; changed seal nipple and circ sleeve and gas lift valves; could not reach packer with same spacing as before; res paced tubing with 8' pup; landed tubing with 15,000 psi on packer; tested tubing with 1000 psi, OK; installed back pressure valve in tubing hanger; rot~t~¥ . 9 to get into packet; tested tubing to 1000 psi; removed BOE and f1arfgêd;~ as tree; tested seals with 5000 psi and 1/411 tubing to 5000 psi, OK. 10/17 Puìle:d ~Jmri.f1~a1veand circ thru 1/4" tubing. Ran Otis retriever for no go plug and PA6lJ.\;d"ç!W,,6~MJ;io~ valve out of plug; j~rred l~o~~ from plug; made 7 runs for plug out œu,.~~tÐOt retrleve plug. Released rlg at mldnlght. Varden Platform. If SIGNED TITLE Dist. Dr1g. Supt. DATE 11/14/68 NOTE-Report on i IS form is required for each calendar month, regardless of the status of operations, and must be filed in duplicatE: with the Division of Mip s & Minerals by the 15th of the succeeding mo nth, unless otherwise directed. ~,. . ......... )</v # ~ /!~wlJ.. l;')Iff'J K~_ l~rnl P-7 SUBMIT IN DUPÚC~ Trt~ I· STATE OF ALASKA _. " ~.;.j ;-' rr 0 t-6-ee otlter In- . (\J ~-:.-: ~..:-- rrw ~~~,~~~~~~ 5.. API NUMERICAL CODE OIL AND GAS CONSERVATION CÒMMtT:téf- r:r 0" ~. m(~ _ 50-133-20131 kJ/ WELL CÒMPLETION OR RECOMPLÉ.,'tION REPdÅI:6A:~7'11l<DG; '-- "', , 6. LEASE DESIGNATION AND SERIAL NO. la. TYPE OF OIl, fVl WELL lAJ ~AESLL 0 . DRY 0 '-- ',"- (\) (\.J C- J(;).ther ,", '. ,-.- . ~ ,....-.' "'"'" ". , ADL 18729 7. IF INDIAN, ALLOTTEE OR TRIBE NAME DEEP- 0 EN PLUG D DACK II.IFF. D nESVR. . ~-'" f'J ¡,..-. I--f ~1her'~:::; r\,} i-~....c h.~~ b. TYPE OF COMPLETION: NEW rVI WORK 0 WELL ~ OYER 2. NAME OF OPERATOR . ¡.- t·~) ...._~ -:~¡ 8. UNIT,FARM OR LEASE NAME Uniog Oil Company of California* 3. AI)DRESS OF OPERATOR N Ç) .....¢ ~:"- 10-....... ...... "(ñ Unit 2805 Derta1i Street Ancho~å e, A1as~a 9950~ '-'- C 4. L()CATIONOF wÈLL:(Reportlocation clearlýanàinaccordatice with anU State requirementsJ'* -I-t s.dac. 761. 3' If, 1131. (i .' E frOm SW Corner, See. 6, TaN, Rl ~ ' '",,-,..,.'" t'~ . .~ ~ o McArthur River 11: SEC., T., R., M., (BOTl'OM HOLE . OBJECTIVE) At top pr(t<l. intervàl reported be!-ow2157' FNL and 665' FEL,..) At total depth. Séc. 7,., T8N, R13W, SM t:; ~ 2: 1- (0 4.. L-<,.~ 2465' FNLand 401'FEL,Sec~ 1, T8N, R13W, S~ o~ ~.".. 0- tr- C\j N (\J r,.,) f\) / .;>\ o. -- ~ ,.. Sec. 7-T8N-R13W-SM " , 12. ~ERMIT NO. 68-62 - r"--4 INTERV ALS DRILLED BY CABLE TOOLS MÐ .-- 23. WAS DIRECTIONAL SURVEY MADE 24. TYI>E ELECTRIC AND OTIiER LOGS'RUN: . Dual ¡"(luction tªterQlo~;,Ga~a Ray; Density, Sonic Caliper, ~pmeter,., Gamma RaYEgrb~ftla¡ÅR3: ,~' 25. CASING RÉCORD (RepOrt all strings set in w~U) \¿ :::2 ....,. Yes , .... .~.r CASING SrZE WEIGtrr, LB/FT. 'GMDE DEPTH?J!;T (MD) HOLE1 SIZE CEl\n;;NTING RECORD AMOUNT PULLED ,; 13.-3/8" . ·.61# ¡J~5 ' ~' 2531' 17-1/21 2400 sac1 '5 y 9":518" 40..43.5..47 N..;80 & 11_3271 12-1/4" 1st: J.j 'rl sacks J' " A~95 ... 2nd: 24 ~ sacxs . c. ... .~+ .' ,. .., 26. . LINER RECORD , 27. <1 .' TUBING REQORD SIZE TOP (MD) BOTTOM (MD) SACKS CEMENT* SCREEN (MD) SIZE _. DEPTH SET (MD) PACKER SET (MD) 1,,--- .. 4-1/2~ lO..~ll· lUt~12' ,.. " ... 3-1/2-rr 1 ° ,:511-] 0 ,546 28. PERFORATIONS OPEN TO PRODUCTION (InteTVal, size and number.) 29. ACID, SHOT, FRACTuRE, CE¡'\!iENT SQUEEZE, ETC. Four boles per' foot: . PEID'rlIII:ITERN AL{MD) AMOUNT AND KIND OJ!' MATERIAL USED 11, 142...11 , 175 ' 10,898·-10,868' '~'TO,628 "V 11 , 11 0~11 , 142 ' 10,846-+0,822' 10,596 "'__c.r . -_._-~. 0 gì .\- 11,078...;11 ,110' 10,798-10,728' --,* --- ~ .... 1 'h 11 ,030;';] 0,918' 10,71a-10,6'78' ,;n c; (0-- rr- '" .....- FLOW. TUBING PREss. ""- 30. DATE OF TEST, GAS-OIL RATIO CASING PRESSURE 1. DISPOSITION OF GAS (Sold, uaed for uel, vented, etc.) 32. LIST OF ATTACHMENTS SIGNED (B . E. Talley) TITLE t,.¡ 1IJ< ... Dis~ D~~g.. ~upt. ~~l· . f"'1'J n..> DATE 10/16/68 (See Instructions and Spaces For Additional Data on Reverse Side) Marathon Oil Compan , Subeperator, Dolly Varden Platform INSTRUCTIONS ,General: This form is designed for submitting a complete and correct well completion report ènd log on all types of lands and leases in Alaska. Item: 16: Indic\"c which elevation is used as reference (where not otherwise shown) for depth-measure- ments given !n :_Iher spaces on this form and In any i111d,.!: IS. Items 20, and 22:: If :hls well IS COl11pleted for sep¿Hdl( Ion fl'or:! n10le thàn one 111!erval zone (multiple completion). so state in item 20, and in iTe'n 2~ show the prcJlJCI11Q interv(11, or intervals, top(s), bottom(s) and name (s) (if any) for only the interval reported in Item 30. SubrTllt c1 separate report (paQe) on this form, adequatelyìdent¡fie~, for each additional intel val to be seperately. produced, show- ing the additional data pertinent. to suc;h interval. Item26: "Sacks Cement": Attached supplemental records for this well shou!d show the details of any mul- tiple stage cementing and the location of the cementing tool. Item 28: Submit d separate cornpletionreport on this form for each interval to be separately produced. (See instruction for items 20 and 22 above). tY ow FORMATION TESTS ¡NCLU)IN(; Iwn:llVAL TE..STf:f>. PH.ESSlJIlE DATA AND HECOVEIUF-S OF OIL. GAS. NAJ\1E 35. GÐOLOGIC MARKERS WATER AND MUD ) 1078' - 11175' . l\IEAS. DEPTH. TRUE VERT. DEPTH SI (Inside) PSI (60 Min.) I I (305 Min.) PS I (420 Mi n . ) SI 5221 PSI (Outside) 4089 PSI 628 PSI 914 PSI 4041 PSI 5583 PSI West Foreland r~i dill e Ground Shoal Top of Hemlock 14 bb1 dead oil 23.20 API, 18 bbl mud cut Oi1(60% 0;1,40% mud) .. DATA. A1-rACl[ BRIEF DESCHIPITIONS OF LITHOLOGY. >OHOSITY. FBACTURES. APPARENT DIPS AND (¡,,:TUTED ~lto\\'s O~' OIL, GAS 011 WATER. . 5,1201 10,5921 11,2951 4,6681 9,5551 ) 10,1451 ^, ,......., 0'1--- FOR'" Ad4 REV. 3-6S I DATE 9120/68 <L MARATHON OIL COMPANY FIELD Trading Bay HISTORY OF OIL OR GAS WELL WELL NO . D-9 LEASE Trading Bay Unit PARISH COUNTY Kenai" Borough BLOCK SEC. 7 TWP. _ 8N 13W R. STATE A1aska- KB ELEV. '106' [TOP- OF OIl. STRING _ ELEV. MEASUREMENTS Top OF ROTARYTABLE._.· EI_EV. TAKEN FROM GRD. OR MAT ELEV. I~ 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 siz, of hole, size and number of bits, completè description of casing, cementing, fishing or drilling difficulties, surveys, all tests, all completion operations and procedure, etc. HISTORY PREPARED By Owen Akins TITLE Area Su~erintendent (Dr1g.) DATE 1968 7/26/68 TD 420' -Moved rig ·to Slot 115, Leg A-2. Picked up 17\" bit. Cleaned .out· piling,from 325' to 420'. RaI).;ßperry Sun Gyro to 420' - 19 hours. Went in hole to spud. .~ . -'-- -- 7/27 TD946'- Ran inwith~-t7\"bit, 7-3/4 x 183' DC, B.S. Drilling with 2000# and 60 rpm from 420 to 660'. Gyro survey showed D-3 and D-9 piling close to each other at 420'. Pulled out and ran Turbodril1 III with 21;.0 kick sub. Faced S54E at 660', d·ri11edto 791'. Pulled out and ran drilling setup. Drilled from 791' to 879'. Hole turned fromS55E to S32E. Pulled out and ran in with Turbodri11 #2 with 1\0 kick sub. - 7/28 TD2240' - Continued drilling with Turbodri11 #2 from 879~ to 978'. Turned hole from S32E to S50E. . Randri11iI1gsetup. Drilled to 1490.'. Tripped to change drilling setup. Drilled to 1898'. Pulled out to change drilling setup and bit. Drilled 12~" hole to 1898-2240'. 7/29 TD.2550'- Drilled andsurveyed12~" hole from 2240' to 2550'. Pulled out of hole. Picked up 171;." Secho1e opener and l7~" 3-point reamer. Opened 12~1f to'17\" hole from 650' to 1965'. Tripped for new hole opener. Opened hole from. . 1965..2027'. (Down 2 hours for repair leak in 4" mud line). 7130 TD 2550' - Opened 12~" hole from -2027' to 2550'. Made trip to bottom of piling. Circulated .on bottom 1\ hours. Spotted 20 sacks nut plug. Repaired 4" mud line. Pú11ed out of hole. Rigged to run 13-3/8" casing. Ran 62 jts 13-3/8" 61/Flft. J-55 buttress Range 3 casing 2481.47' ,net pipe landed at 2530.97' as stated below. . Ran centralizers on bottom 4 jts, welded collars on bottom 3 jts and top 2. jts. Shoe at 2530.97', collar at 2492.27'. Circulated hole clean. Cemented casing. 13-3/8" Casing Detail KB to Top of casing 61 jts 13-318" 61# J-55 buttress csg. 1.Fi1lup Collar 1 jt13-318" 61/1 J-55 buttress csg. 1 Float Shoe . Effective 44.80' 2447.47' 2.00 ' 34.00' 2.70' FroÌn -0' 44.80' - 2492.27' - 2494.27' - 2528.27'- - To 44:80 ' 2492.27' 2494.27' 2528.27' 2530.97' 7/31 TD 2559' - Cemented 13-3/8" casing with 2000 sacks Class G with 6% gel, 14#/ga1, mixed in Inlet: water~nd 400 sx Class G in fresh water l5.7/1/gal, total mixing time lhour 25mins. Displaced plug with rig pump with 328 bbls mud in 31 mins. Bumped plugwfth 1500 psig, held OK. Cement in place at 8:45 AM 7-31-68. Estimated' 400 sacks cement return tlith good circulation throughout job. Níppledup.)?í"és?sure tested BOPE in 3000 psi; OK. Pressure tested casing with 1500 psig, OK. Repaired mud line. Started picking up drilling assembly. 811 TD3534' -Drilled plug and float collar at 2492' and tested 13-3/8 to 1500 psi, OK. Drilled out shoe at 2531' and cleaned out to 2550'. Drilled 12~" hole and surveyed from 2550'to 3463'. Hole turned from S49E to S45E. Pulled out and' ran 13 turbodrill 6-3/4f1and 2\0 kick sub - faced S55E. Drilled to 3534'. Pulled out to run drilling setup. (> FORM 484 REV. 3-63 DATE r,\ ,.--..... PAGE 2 MARATHON elL CDMPANY HIS'TORY OF OIL OR GAS WELL FI ELD WELL NO. D-9 STATE LEASE 'Trading Bay Unit PARISH COUNTY BLOCK SEC. TWP. R. fTOP OF OIL STRING ELEV. MEASURE~ENTS . Top OF ROTARY TABLE_. ELEV. 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 1968 8/2 8/3-10 8/11 8/12-13 8/14-16 8/17-18 8/19":22 8/23 8/24 ELEV. HISTORY PREPARED BY TITLE TD 4000' - Ran in hole with drilling setup and cleaned out to 3534'. Pulled 2' off bottom and drill pipe parted in box. Pipe parted at 115' KB leaving I' of box up on fish. Ran Bowen outside cutter and cut off box. Ran Bowen overshot with 5" basket slips and pack off. Engaged fish and pulled out of hole. Laid 6 crooked jts and changed bit. Drilled and surveyed l2~" hole at 4000'. TD 8666' - Drilled and surveyed l2~" hole. Pump pressure dropped off 450 bbls. Pulled out of hole to check for washout. TD 9034' - Pulled 6 stands and found 3" crack in new hard band on drill pipe box. Laid down 8 jts with new hard band. Ran back to bottom, drilled from 8666' to 8721'. Measured out of hole, measure OK. Drilled l2~" hole from 8721' to 9034'. TD 9655' - Drilled and surveyed 12~" hole. Pump pressure decreased from 2350~ to 1950··psi. Checked pumps, OK. Pulled wet string and watched for washout. Found washout in shaffer bumper sub. (2 inches long and ~"wide). Washout was in bottom of fine thread box, l' down from top end of bumper sub. Ran in hole. Drilled 12~" hole from 9410' to 9655'. Pulled out of hole to change bit. TD 10,372' - Drilled and survéyed 12Jz;" hole. Pulled up into casing for electrical shutdown to connect new gas turbine. 10,752' - Drilled and surveyed l2Jz;" hole. Measured out of hole, no correction. Top of Hemlock at 10,600'. TD 11,341' ... Drilled and surveyed 12~" hole. One hour circulating up sample. Pulled 20 stands. Ran back to bottom, circulated and conditioned mud 2~ hours for logs. Surveyed and pulled out to run logs. Rigged up and started in hole with logs at 1:00 AM. Ran DIL-latero10g from 11,346-2532' (Schlumberger TD 11,346'). Ran Gamma-Ray Density log. TD 11,341' - Continued logging. DIL 11,346-2532', Density, Gamma 11,346-2532'. Sonic log with caliper 11,335-2535'. Dipmeter 11,335' to 9500' shorted out. Through logging at 10:00 AM 8-23-68. Ran in hole with bit to 11,341'. Circulated and conditioned mud for casing. Pulled out of hole. Rigged up to run 9-5/8" csg. Cut drill line, changed to 9-5/8" rams. 30 jts 9-5/8" csg in hole at 7:00. TDl1,341' - Continued running 9...5/8" casing. Ran 270 jts 9-5/8" csg, shoe at 11,327', float at 11,281~, DV at 6966'. Circulated csg at 5:00 PM to 7:00 PM. Started cement pump and cement'manifold and lines were cemented up, continued circulating casing with rig pump while cleaning out manifold. Bypassed cement line and used kill line for cement line. Started mixing cement at 11:45 PM Stage 1, 500 gallon mud. sweep ahead of 720 sacks Class G with 6% gel, 0.5% R-5mixed in 122 bb1s salt water, 600 sacks neat with 0.5% R-5 and 0.8% D-31 mixed in 72 bbls fresh water. Mixing time 75 mins. Displaced with rig pump. 750 psi to 1500 psi. Bumped plug with 2000 psi - floats held OK. Dropped bomb, opened DV tool with 900 psi, circulated 60 mins. Trace of cement. Stage 2 - 500 gallons mud sweep ahead of 1148 sacks Class G with 6% gel mixed in 230 bbls salt water, 100 sacks ne~t with 2% CACL2, 12 bbls with mixing time 65 mins. Displaced with rig pump, ·4Sminutes. Shifted DV with 2500 psi. Job complete 0630 8-25-68. ·~ r~vR!~¡ -~ C':, r~f:·.'. ~- ~~ ~'_. DATE PAGE 3 MARATHDN OIL CDMPANY FIELD HISTORY OF OIL OR GAS WELL [ToP OF OIL STRING ELEV. MEASUREMENTS . , Top OF ROTA. RYTABLE_ELEV. 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 weU, 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. WELL NO. D-9 Trading Bay Unit PARISH COUNTY BLOCK SEC. LEASE STATE ELEV. HISTORY PREPARED By TITLE DATE 1968 9-5/8" Casing Detail KB to Top of casing 111 Jts 9-5/8" 40lF N-80 Buttress 38 jts 9-5/8" 43.5fÞ N-80 Buttress 15 jts 9-5/8" 47# N-80 Buttress 1 Howco DV Collar 22 jts 9-5/8" 47ft N-80 Buttress 82 jts 9-5/8" 471ft S-95 ST&C 1 Howco Fill Collar 1 jt 9-5/8"47/1 S-95 ST&C 1 Howco Float Shoe 42.88' 4711.41' 1575.41' 636.43' 2.13' 940.06' 3375.44' 2.00' 41~72' 1.90' TWP. R. 0' 42.88' 42.88' - 4754.29' 4754.29' - 6329.70' 6329.70' - 6966.13' 6966.13' - 6968.26' 6968.26'·- 7908.32' 7908.32' - 11,283.76' 11,283.76' - 11,285.76' 11,285.76' - 11,327.48' 11,327.48' - 11,329.38' 8/25 PBTD 11,281' - Nipp1ed up. Tested BOPE with 3000 psig, OK. Tested casing with 2000 psig, OK. Tripped into DV, tagged at 6964'. Drilled DV collar, tested casing to 2000 psig, held OK. Tripped to cement at 11,100' (140' above baffle plate). Drilled cement to float collar at 11,281'. Tested casing to 2000 psig, held OK. Circulated mud for 2 hours. Prepared to displace with diesel. . . 8/26 PBTD 11,281' - Displaced mud in hole with 758 bb1s diesel. Displaced diesel in hole with mud. Conditioned mud 4 hours. Rigged up Dresser Atlas. ~ Bond Log and Gannna Ray Correlation log from 11,285' to 9000'. Made one run ~forating guns from 11,142' to 11,175', dual induction log measurement. Dresser Atlas PBTD at 11,290'. Log shows good cement bonding throughout logged interval. 8/27 11,341' - Finished perforating for DST #1, Run two 11,110-11,142' and Run 113 11,078-11,110' off of dual induction log measurements. Rigged down Dresser Atlas. Ran in hole forDST 1 of perforations 11,078' to 11,175' and Halliburton packer at 11,048', anchor at 11,062'. Opened tool for 5 minute initial flow with strong blow of air. Shut in tool for 60 minute initial shut in. Opened tool at 3:39 PM for 305 minutes. Second flow period. Shut in at 8:42 PM for 420 minute final shut in to 6:42 AM 8-28-68. During 305 minute flow test, had strong blow of air immediately through 2~ hours flow, decreasing to fair after 3 hrs, and very poor after 3~ hrs and through remainder of flow. No gas or liquid to surface. Reversed out 11 bbls fresh water cushion mixed with 14 bbls of heavy black dead oil, 23.20 API gravity at 600 F (uncorrected for water cut) and 18 bbls of mud cut oil, estimated 60% oil, 40% mud. Cut on oil sample 29.7% water and 0.3% emulsion. Water titrated at 425 ppm chloride. Unseated packer. Pulled out of hole . - 8/28 Finished pulling out of hole with DST #1. Recovered 60' rat hole 10 gallon sand ftbQve DCIP valve. Recovered small oil cut mud sample from DClP valve, which was 35% oil and 65% mud emulsion. DST IFl PRESSURES IlllI IClP IFP FFP FSIP FHH Inside' Chart 493211 4069 (60 min) 623 909 (305 min) 4021 (420 min) 4932 Outside Chs-rt 522lifl - 4089 628 914 4041 5583 f" FORM 48'¡ ru:V.3-63 l~ . DATE PAGE 4 MAI~ATHDN OIL COMPANY FIELD HIS-¡rORY OF OIL OR GAS WELL [ToP OF OIL STRING ELEV. MEASUREMENTS .TOP OF ROTARY TABLE_ ELEV. TAKEN FROM . GRD. OR MAT ELEV. It is of the greatest importance to hove a complete history of the well. Use this form in reporting the history of all important operations at the well, togefher with the dotes thereof, including size of hote, size and number of bits, complete description of casing, cementing, fishing or drilling difficulties, surveys, all tests, all completion operations and procedure, etc. WELL NO. D-9 BLOCK SEC. LEASE Trading Bay Unit PARISH COUNTY STATE ELEV. HISTORY PREPARED By TITLE DATE 1968 TWP. R. Ran in hole with drill pipe. Pulled out laying drill pipe down. Rigged up Dresser Atlas and ran 8-1/8 gauge ring. Ran Dresser AGT 364; to 53/ft. 9-5/8'~ packer and set at 10,512'. Tail at 10,545'. Rigged up to run _4\" tubing. 8/29 PBTD 11,281' - Rigged up to run 4%" tubing. Motor shorted out on tong unit changeout motor. Ran 322 jts 4%" 13.6# N-80 Tubing. S.paced out and set 11,000/1 on AGT packer at 10,512'. Removed BOE and riser. Flanged up Xmas tree. Tested~" tubing to 5000 psi, OK. Tested tree to 5000 psi, OK. Rigged up Dresser Atlas. Pulled dummy valve. Displaced mud with diesel down casing through sleeve. 4%" Tubing Detai1~ Elevation CIW Hanger 4%" 12.611 N-80 Seal Lock Pup Jt 8 jts 4%" 12.64; N-80 Seal Lock Tbg 4%" Seal Lock x Buttress X-Over 4%" Ball Valve 4%" Buttress Seal Lock X-over 84 jts 4%" 12.641 N-80 Seal lock tbg VI C2F 145 MHF 31# 1770 710# 55 jts 4~" 12.611 N...80 Seal lock tbg V2 C2F 144 MHF 31# 1768 845# 43 j ts 4%" 12. 6/ft N-80 Seal Lock tbg V3 C2F 146 MHF 31# 1767 910#. 30 j ts 4~" 12. 6/! N-80 Seal Lock tbg V4 C2F148 MHF 31 IF 1764 10501/: 31 jts 4~" 12.61! N-80 Seal lock tbg V5 C2F 140 MHF 31 #1762 1110# 9 jts 4~" 12.6# N-80 Seal lock tbg V6 C2F 139 MHF 31 #1761 118011 9 jts 4%" 12.6# N-80 Seal Lock tbg V7C2F 132 MHF 311ft 1759 123011 9 jts4~" 12.6# N-80 Seal Lock tbg V8C2F 142 MHF 31 #1767 1280# 9 j ts 4%" 12.6/1 N-80 Seaì lock tbg V9 C2F 135 MHF 31 #1755 1315# 9 jts 4%" 12.6ift N-80Sea1'Lock tbg V10 C2F 131 MHF 31 #1750 1340# 6 jts 4\" 12~6# N-80 Seal'Lock tbg VII C2F 147 MHF 31 #1750 1390# 6 j ts4~" 12. 64ft N-80 Seal Lock tbg V12 C2F 136 MHF 31 #1748 1395# 6 j ts 4~1I 12. 61ft N-80 Seal Lock Tbg V13 C2F 143 MHF 31 # 1746 1430# 6 jts 4%" 12.6/1 N-80 Seal Lock tbg V14 C2F 149 M 73# 1393 1480# 1 jt 4%" 12.611 N-80 Seal lock tbg 4~" Seal Lock X Buttress X-over 4%" XO Circulating Sleeve 4%tt Buttress X Seal Lock X-over 42. 15 t. 1.00' 3.50' 249.93' 1.77' 3.00' 1.91' 2709.49' 4.40' 1765.45' 4.40' 1382.32' 4.40' 973.12' 4:40 ' --ï ÕT2:-2j-' -----..-.- 4.40' 285.63' - 4.40' 248.58' 4.40' 294.15' 4.40' 294.56' 4.40' . 295.25' 4.40' 195.25' 4.40' 194.70' . 4. 40 ' 195.82' 4.40' 190.61' 4.40' 33.55' . 1. 68 ' 4.35' 1.87' . ( 1. 00) 41. 15 ' 41.15' 42.15' 42.15' - 45.65' 45.65' - 295.58' 295.58' - 297.35' 297.35' - 300.35' 300.35' - 302.26' 302.26' - 3011.75' 3011.75' - 3016.15' 3016.15' - 4781.60' 4781.60' - 4786.00' 4786.00' - 6168.32' 6168.32' - 6172.72' 6172.72' - 7145.84' 7145.84' 7150.24' .__ .~. __....._.___A___..._.... 7150.24' - 8162.47' 8162.47' 8166.87' 8166.87' - 8452.50' 8452.50' - 8456.90' 8456.90' - 8741.48' , 8741.48' - 8745.88' 8745.88' - 9040.03' 9040.03' - 9044.43' 9044.43' - 9338.99' 9338.99' - 9343.39' 9343.39' - 9638.64' 9638.64' - 9643.04' 9643.04'9839.29' 9838.29' - 9842.69' 9842.69' - 10,037.39' 10,037.39' - 10,041.79' 10,041.79' --10,237.61' 10,237.61' - 10,242.01' 10,242.01' - 10,432.62' 10,432.62' - 10,437.02' 10,437.02' - 10,470.57' 10,470.57' - 10,472.25' 10,472.25' - 10,476.60' 10,476.60' - 10,478.47' ! . . f ,r-- " ,~ FORM 48,4 R~V.~·~;J DATE PAGE 5 MARATHON. DIL COMPANY HISTORY OF OIL OR GAS WELL FI ELD Trading Bay Unit PARISH COUNTY BLOCK SEC. TWP. R. WELL NO. D-9 LEASE . STATE ELEV. [ToP OF OI,L STRING 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 reporti~g the history of all important operations at the well, together with the dates thereof, including size of hole, size and number of bits, complete description of casing, cementing, fishing or drilling difficulties, surveys, all tests, all completion operations and procedure, etc. , . DATE 1968 ~- -..---------..... -- .--.. -"~, .. - _.- ...-'---. '-"~- . . __._h_..__~___·.._·_. 1 jt 4~"12.6# N-80 Seal Lock Tbg 31.80' 10,478.47' - 10,,510.27' 4%" Box x 3~" Pin Seal Lock Sub .52' 10,510.27' - 10,510.79' 3~" Seal Lock Box x 3%" EUE 8 pin sub .88' 10,510.79~ - 10,511.67' 3~" "p" Landing Coupling .36' 10,511.67' - 10,512.03' 8~" "P" Landing Coupling , .32' In Packer 4'- 4750 AI Seal Nipples 5.69' In Packer 9-5/8" 53. 5fft AGTPacker 3.18' 10,512.03' - 10,515.21' 5~ 8rd Extension Tube 4.51' 10,515.21' - 10,519.72' 5~fI 8rd Coupling .55' 10,519.72' - 10,520.27' 5~" x 3~" 8rd Swage .53' 10,520.27' - 10,520.80' 3~ff EUE 8rd N-30 Púp Joint 6.11' 10,520.80 ' - 10,526.91' 3~" "X" Nipple .88' 10,526.91' - 10~527.79' 3~tI EUE 8rd N-80 Pup Jt 6.04 ' 10,527.79' 10,533.83' . 3~tI "Q" Nipple 1.32' 10,533.83', - 10,535.15' 3%" EUE 8rd N-80 Pup Joint 10.04' 10,535.15' - 10,545.19' 3~" Wing Guide 8.125 OD .70' 10~545.19' - 10,545.89' .. ~..-_...._-~--_..-_. -- ._<- .-~- ------.- - Total 322 jts 4~" 12.6# N-80 Tubing. 8/30 PBTD 11,281' - Closed circulating sleeve, tested to 1000 psi on csg for 30 mins, OK. Rigged up Dresser Atlas and started perforating at 11:30 AM. Perforated with 2" slimkone, 4 holes per ft. Tubing gun, perforated at 11,030-10,418', 10,898-10,868',10,846-10,8221, 10,798-10,728', 10,628-10,596', 10,678-10,712'., Through perforating at 6:30 PM. Well flowed while perforating. Shut well in . to rig down Dresser Atlas, 400 psi on tubing. Well continued flowing. Released rig at midnight 8-30-68. 9/10/68 NOTE: 7 AM Tubing pressure 400# casing pressure 200#. 'Rigged up Otis wireline unit and opened Otis type "XO" circulating sleeve at 10,472'. Rigged up'BJ cementing company and pumped 170 bb1 diesel down 9-5/8 x 4\" casing annulus with returns out 4~fttubing. Otis ran XO sleeve closing tool to 10,490'. Rigged up Nowsco and pumped 174,040 cu ft of nitrogen down 4~" tubing with returns out casing annulus. Final pumping pressure 2500#. Latched Otis circulating sleeve and jarred closed. Reran through sl~eve three times, unable to látch sleeve indicating sleeve is closed. BJ pumped 50 bb1 diesel down casing annulus to check circulating sleeve closed. Casing pressure increased from 500 to 1200#, tubing pressure increased from 2500 to 2900#. Rigged down Otis, shear pins in shifting tool had not sheared indicating that the sleeve is closed. Bled casing,þressure from 1200 to 200041, tubing pressure decr~ased from 2900 to 2550#. From all indications, it appears that the packing in the circulating sleeve is cutout. Opened well on a one inch choke at 5:00 AM, tubing pressure 2550#, casing pressure zero. Tubing pressure decreased to zero in 15 minutes, casing on strong vacuum well dead - no fluid to surface. Hole No. 1 - our wireline units did not handle shifting tools. Low gear will pull only 250#. Otis sent out one of their slick lines for D-lO. With Rig 76 in present position - cannot utilize enough lubricator to install a pack off across sleeve. " Fa"'" .a 04 tH. 'If. 3'-Ò3 _ ,::;... ,"- . ............ ' -..., M¡:~_ JATHON elL CCMP- ~'NV HISTORY OF OIL OR GAS WELL FIELD D.Al'E" 1-6-70 -) Þo 4. WELL NO, D-9 LEASE BLOCK SEC. TvVP. R. STATE PAI~ISH COUNTY ELEV. MEÄSUREMENTS TAKEN FROM rTOP OF OIL STRING ELEV. [ToP OF ROTARY TABU:':~ ELI:v. GRD. OR MAT· ELEV.. H..ISTOHY PREPARED By TITLE ----- It is of the greatest impartcnce to hove (1 comple!e history of the well. Use this fo,-m in rerJorting Ihl! hi~lory of nIl important operations at the well, toçcthcr with the dotes thereof, including 5ize of holo, :>ize ond number of bits, complete description of ca~in'J, cementing, fi~hing or drilling difficuitics, surveys, oil tests, ail complctionoperolions und procedure, etc. -_._------------------~---------_._------_._---------~--..------- . --------_._---_._--~--_. ---- . .------- PATE '. 10/27 PE 11,153 ... 11= r~h~"· . ~~.~~ Hoved rig from D-17 to D-9 at 4:00 PM ~0-27-69.. Rigged up Schlumberger and tested lubricator to 3000 psi - OK. Ran production profile. Rig released at 5.00 AM 1q/28l6~." ". ~ , '.... '. , ( " I . f~Îi>. ~;.':"-... iI ¡...,..) \ .. ¡; '',.. CW1SION OF Oft Aìiù G f roo ANCHOR/.~~ 4 ¡~ ... '" .. 7-17-69 ~. ,~ I ' MA..~AT:-10N elL C:CJM~..-\NV Hi'STORY OF OIL OR GAS WELL FIELD "'cl1rthlft'-.Ri V9f·· FCIt~ 4H.a 1t,"V, 3-ft3 . p),\ Tí.~: \. STATE Alaska LEASE Trading Bay Unit ~~¥~U 'COUNTY Kenai Borough 106' ELEV. KB BLOCK SEC. 6 756 N/S, 1138' E/W TWP. 8-H ~ 13-W WELL NO. 0-9 H,.'STORY PREPARED By. H. D. Lee rTOP OF OIL STRING __ ELEV. MEASUREMENTS l Top OF ROTARY TABLE_ ELEV. TAKEN FROM l( GRD. OR MAT . ELEV.__ his of thegreoJest imparlance to hove acamplele hislory af the well. Use this form in reporting the history of 0!1 imporlonl operations at the well,togethcr with the dates thereof, including ~izc of holc, 5 izc and number of bib, complete description of cosin'd, cemcnling, fishing or dri!ling difficuities, surveys, 011 tests, 011 completion operations and procedure, etc. TITLE Foreman -----~-===----_-==.=====----===:-===-===..:..---====---------------===---:=...~-==--====--===--====.:.=:::-~-====:::--==--===----===--======= DATE TO 11341, TVO 10184·, PBTO 11281, TVD 10133 9-5/8".Casing at 11:32'7' . 'I..¡ ,!I 3/10/69 Started moving rig to 0-9 at 12:00 midnight 3/10/69. Rigged up, now bleeding pressure off of \^lell.·, Plan to attempt to pull Otis plug. from tail pipe, if we are unable to, will tu~.tail pipe above plug. Bled pressure off of well.· 3/11/69 11281 Made one run with Otis retrieving tool to pull "QII plug at. 10,544' latched onto plug'but retrieving tool pulled loose each time. Pulled out of hole. Rigged up Dre~~er Atlas, ran Dia-log jet cutter. Cut tail pipe at 10,540'. Checked plug, was still in place, reran Oia-log cutter second time, cut tail pipe at 10,540'. Checked plug. Plug was gone. Released rig at 3:30 p.m. 3-11-69. . 200# on tub; ng before cut , . noincreâse in' pres sure after cut. ' 4/25 paTD 11~28l Mo'ved rig from 0-19 to 0-9 to reperforate Hemlock formation. Rigged up and began perfor·ating at 9:00 p.m. Schlumberger ran collar 10cation,log from their TD of 11,042' to 10,500'. Correlated collar & reperforate with 2 hyper jets/ft using 2'scal1op gun, from 11,030-10,918, 10,898-10,868 & 10,846-10,822 in 20' sections. Wellhead pressure. prior to start of reperforating 150 psig. Pressure to 300 psig. Reperforating Hemlock formation. 4/26 PBTD 11,281 Completed reperforating Hemlock formation.· Reperforated \^lith 2 hyper jets/ft using Sch1umberger2" scallop gun from 10,798-10,728',10,628-10,596' & 10,678-10,712' in 20' sections. Wellhead pressure increased from3GO psig to 525 psig during re- perforating.. Reran collar locator log in an attempt to record perforated interval with no success. Job completed at ô:30 p.m. Rigged down Sch1umberger and hooked up well head for a short production test. Unable to get well kicked off. Started moving rig to D-19 at 4:30 a.m. Released rig at 6:30a.m. Tested well but unable to get and valid test of production rates. to extremely .low productivity. Well shut in due J,.¡I.. ~ i'~'~ . . " ~j " \ . J:;l'IJ$ION OF 0''. ANQ C/.5 '\ A1'iCHO&.G~ . FORM 484 . _....~.- , REV. 3-(\3 . ,~ . /'~" AUQust 19.. 1969 MARATHON CIL CCMPANV HISTORY OF OIL OR GAS WELL FJELD MrArthqr River pATE WELL NO. 0-9 LEASE Trading BaY'Unit PARISH COUNTY Kenai Borough BLOCK SEC. 7 TWP. RN R. 1 ~ \AI STATE Alaska . KR ELEV. 106 ' TITLE John R. Barber Production S~perintendent , ITOP OF OIL STRING· ELEV. MEASUREMENTS Top OF ROTA.RY TABLE_ ELEV. TAKEN FROM GRD. OR MAT ELEV._ H,.ISTORY PREPARED By It is of the greotest importance to have a complete history of the well. l)se this form in reporting the history of 011 important operotions ot the well, together with the dotes thereof, including size of hole, size ond number of bits, complete description of cosin'J, cementing, fishing or drilling difficuities, surveys, all tests, 011 completion operations ond procedure, etc. DATE 7/20/69 PB 11,281' Moved on D-9. Rigged up Otis wireline lubricator. Attempted to shift sleeve. Attempted to circulate. Filled tubing with 203.bbls. Maximum tubing pressure 2200 psi. Would not circulate. Went in hole and jarred on sleeve. Pulled out and attempted to circulate hole. Pumped in at 1700 psi and 2 bbls/min. Casing pressure bled down to 200 psi. Well will not circulate. Waited on tubing perforations. PB 11,281' Rigged up and perforated 8 shots in the tubing at 10,465' tQ 10,467'. Checked PBTD at 11,142' (139' of fill). Pressured up and' would not circulate. Perforated with 8 shots at 10,465' to 10,467'. Could not break circulation. Reperforated at 10,365' with 4 shots, broke circulation. Set back pressure valve in tubing. Removed tree and installed BOP's. Picked up two joints of tubing to test BOPs. Tested BOP and hydri1. 7/22 P.ß 11~28l' 7/21/69 Tested BOP to 2500 psi~ OK. Pulled out of hole with tubing and laid down gas lift valves and mandrels. .Changed pipe rams in BOP. Picked ùp fishing tools and went in hole. Tagged packer at 10,504' and started milling. Milled on packer. 7/23 PB 11~28l'. Milled over packer and pulled packer out of well. Picked up and ran 8-1/2'1 bit and casing scraper. Washed from 11,111' to 11,152'. Pushed old fish (which is cut off tail pipe) to 11,152'. Circulated hole for 4 hours. Pulled out of hole laying down 51t drill pipe. Rigged up Dresser Atlas lubricator to perforate. 7/24 PB 11,152' Perforated Hemlock formation with casing jet gun, 2 shots per ft as follows: 10,596-10,628', 10,678~10,712', 10,728-10,798', 10,822-10~846' ~ 10~868-10,898' ~ 10,918-11,030',11,070-11,153'. Ran tubing string with packer at 10,476'. Landed tubing and nipp1ed up. 7/25 PB 11 ,152' Landed tubing with ball valve in place. Nipp1ed down BOP's and installed tree. Tested tree to 5000 psi - OK. Displaced mud with diesel and set packer. Released rig at 1630 7/25/69. Waited on .compressor repairs to kick off well. 7/26 PB 11,152' Well shut in. Waited on compressor repairs to kick off well. :' If:) \ l;1VlSION OFO!lAND G",.. ANCHOR/.G.Q "0.> WELL NO 0-.9 LEASE Trading Bay Unit PARISH COUNTY Kena i Pen Borough BLOCK SEC. 7 TWP. 8N I fv') (11 -I} River- AA ~ IJ.j}:} t/-·I' -<./ , ·fí 13fJ .~ .--.., DATE Oec~mber;31. 1968MARATHDN OIL COMPANY HISTORY OF OIL OR GAS WELL FIELD McArthur R. STATE Alaska KB ELEV. 106' fTOP OFOU.. STRING ELEV. MEASUREMENTS TOp Of' ROTARVTAB.LE_ E LEV. TAKEN ·FROM GRD. OR MAT . ELEV. It is of the greCltest importance to. have a complete history of the well. Use this form in reporting the history of all important operations at theweU, together with the dates thereof, including size of hole, size and number of bits, complete description of casing, cementing, fishing or drilling difficulties, surveys, aU tests, aflcompletion operations and procedure, etc. HISTORY PREPARED BY John R. Barber TITLE Production Superintendent DATE 1968 SETTING BALL VALVES 12/21/68 Rigged up lubricator and wi reline unit to run ball valve. Tested lubricator to 4000#. Ran ball valve. Ball valve would not go in mandrel. Pulled ball valve. Ball valve had heavy wax on valve. Rigged down. Well will have to be cleaned up before ball valve can be seated. . \ \\tti~~tu . J~N 1 7 '\9ß9 . Of oU. J>.~o GAS pW1S\O~\'\'HQF.Þ.'3~ M""'A~H C!,N··O',I L, Cp MP;ÑV HIS-rORY OF' OIL OR GAS~W¿:LL .I X/l f,"\ tf>{ .~ ?<: R. 13VL- ". > DATE Nov. 26, 1968 . . FIELD LEASE Trading Bay Unit PARISH COUNTY Kenai Borough KB ELEV. 106 ' BLOCK SEC. 7 TWP. 8N WELL NO. D-9 [ToP OF OIL STRING ELEV. M EASUREM ENTS T';P OF ROTA. .RY TAB..LE_ELEV. 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, fishångor drilling difficulties, surveys, all tests, all completion operQtions and procedure, etc. STATE DATE 1968 9./10/68 10/14 10115 10/16 Alaska HISTORY PREPARED By John Barber Area Super. ( Prod) TITLE DEC 24 1968 WORKOVER - REPAIR LEAKING CIRCULATING SLEEVE DIVISION OF OIL AND GAS ANCHORAGE 7 AM tubing pressure 40041, casing pressure 200fJ:. Rigged up Otis wireline . unit and opened Otis type "XO" circulating sleeve at 10,472'. Rigged up BJ cementing company\~rtd pumped 170 barrels diesel down 9-5/8. x 4~fI casing annulus with returns out4~" tubing. Otis ran XO sleeve closing tool to 10,490'. Rigged up Nowsco and pumped 174,040 cu ft of nitrogen down 4%" tubing with returns out casing annulus. Final pumping pressure 2500/1. Latched Otis circulating sleeve and jarred closedo Reran through sleeve three times, unable to latçh sleeve indicating sleeve is closed. BJ pumped 50bbls diesel down casing annulus to checkcirculatiog sleeve closed. Casing pressure increased·from500 to12001J:, tubing pressure increased from 2500 to 2900if:. Rigged dcrwn Otis, shear pins in shifting tool had not sheared indicating that the sleeve is closed. Bled casing.pressure from 120011 to 2000ff, tubing pressure decreased from 2900=11 to 25501Þ. From all indications, it appears that the packing in the circulating sleeve is cut out. Opened well on a one inch choke at 5:00 AM, tubing pressure 25501J:, casing pressure zero. Tubing pressure decreased to zero, in l5'ominutes, casing on strong vacuum well dead - no fluid to surface. . Note - - Our wire line units did not handle shifting tools. Low gear 1;<1ill pull only 250#. Otis sent out one of their slick lines for D-lO. With Rig 76 :i,.p p'!:'esßnt position - cannot utilize enough lub.ricator to install. a pack off across sleeve. PBTD 11,341' - Moved rig from D-ll to D-9. Rigged up Otis and ran 3%" Type "Q" no go plug. Set plug bottom Q nipple at 10,533'. Pulled out and rigged up BJ to tubing head to circulate hole clean with diesel. PBTD 11,281' - Displaced hole with 740 bbls""'diesel followed by 164 bbls 9.4:fl/gallon salt water down tubing. Displaced tubing and annulus with fresh water, tested Q plug in nipple at 10,533' to 1000/" held OK. Bled pressure to zero, well dead. Removed Xmas tree, installed back pressure valve in tubing hanger. Nipp1ed up BOPS. Ran landing joint to tubing hanger. Landing joint would only make up four rounds. Pulled landing joint threads, showed slight amount of Gaulding. Removed BOPS and found back pressure valve not· screwed into tubing hanger far enough to permit joint makeup. Nippled up BOPSt installed dummy ball valve and' tested BOPS to 2500# for 15 minutes, held OK. Pulled tubing hanger and seal assembly from Guiberson AGT packer. Pulled tubing. Had 20 stands (1900') pulled. PBTD 11,281r - Continued pulling tubing out of hole. Circulating sleeve was closed and had pieces of rubber in ports. Sleeve was not washed out. All seal nipple was in good condition, mark on bottom of seal nipple showed it had set on top of packer. C11anged seal nipple and circulated sleeve and ran in hole with tubing changing gas lift valves on way in hole. Could not reach packer with same spacing as before. Respaced tubing with 8' pup. Landed tubing with l5,0001! on packer. Tested down tubing with 1000 psi, test OK. Pulled up 9' and changed over to dies~J. down tubing. Pulled up and installed back pressure valve in tubing hanger. Rotated tubing to get into packer. Tested ~uLing to 1000 psi. Removed BOE and flanged XIl1ast:ce~. ~r:~t;::.d senls with 5000 psi. Test t" tubing to 5000 psi, OK. Ris:u!;ed up Otis braided line to Dull dummv valv~ òt:t of storm choke. }: , ,_M ~. ,~. I <:tV) DATE Nov. 26, 1968 M>AR·AT·H0 I\!: ÐII. COMPANY FIELD HlSTORY OF OIL. OR GAS WEl.L I :/ Jfi.../ . i ;Vii ðt$ .K- . . LEASE Trading Bay Unit PARISH COUNTY Kenai Borough KB ELEV. 106 ' BLOCK SEC. 7 TWP. 8N R. l3W_ WELL NO. D-9 Alaska [ToP OF OIL STRING . ELEV. MEASUREMENTS .T.OP OF RO.TARY TABLE_ . ELEV." TAKEN FROM . GRD. OR MAT ELEV. It is of thegreatðst 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, 011 tests, all completion operations and procedure, etc. STATE DATE 1968 9/10/68 10/14 10/15 HISTORY PREPARED By John Barber Area Super. ( Prod) TITLE WORKOVER -. REPAIR LEAKING CIRCULATING SLEEVE 7 AM tubing pressure 400#, casing pressure 200#. Rigged up Otis wire1ine unit and opened Otis type I'XO" circulating sleeve at 10,472'. Rigged up BJ cementing company and pumped 170 barrels diesel down 9-5/8 x 4~" casing annulus with returns out 4~1f tubing. Otis ran XO sleeve closing tool to 10,490' . Rigged up Nowsco and pumped 174,040 cu ft of nitrogen down 4~" tubing with returns out casing annulus. Final pumping pressure 250011:. Latched Otis circulating sleeve and jarred closedo Reran through sleeve three times, unable to latch sleeve indicating sleeve is closed. BJ pu~ped 50 bbls diesel down casing annulus to check circulating sleeve closed. Casing pressure increased from 500 to l200{I:, tubing pressure increased from 2500 to 2900/1. Rigged dOt.¡n Otis, shear pins in shifting tool had not sheared indicating that the sleeve is closed. Bled casing pressure from 120011 to 2000/', tubing pressure decreased from 290011 to 2550/J:. From all indications, it appears that the packing in the circulating sleeve is cut out. Opened well on a one inch choke at 5: 00 AM, tubing pressure 255011, casing pressure zero. Tubing pressure decreased to zerocin 15 'minutes, casing on strong vacuum well dead - nO fluid to surface. ·Not~ - - Our wire line units did not handle shifting tools. Low gear will pull on1y2501ft. Otis sent out one of their slick lines for D-10. With Rig 76 in present position - cannot utilize enough lubricator to install a pack off across sleeve. PBTD 11,341' - Moved rig from D-11 to D-9. Rigged up Otis and ran 3%tt Type "Q" nQgo plug. Set plug bottom Q nipple at 10,533'. Pulled out and rigged up BJ to tubing head to circulate hole clean with diesel. PBTD 11,281' - Displaced hole with 740 bbls diesel followed by 164 bb1s 9.4/Þ/gallon salt water, down tubing. Displaced tubing and annulus with fresh water, tested Q plug in nipple at 10,533' to 1000/1, held OK. Bled pressure to zero, well dead. Removed Xmas tree, installed back pressure valve in tubing hanger. Nippled up BOPS. Ran landing joint to tubing hanger. Landing joint would only make up four rounds. Pulled landing joint threads, showed slight amount of Gaulding. Removed BOPS and found back pressure valve not screwed into tubing hanger far enough to pennit joint makeup. Nippled up BOPS, installed dummy ball valve and · tested BOPS to 2500# for 15 minutes, held OK. Pulled tubing hanger and seal assembly from Guiberson AGT packer. Pulled tubing. Had 20 stands (1900') pulled. 10/16 PBTD.ll,28l' - Continued pulling tubing out of hole. Circulating sleeve was closed and had pieces of rubber in ports. Sleeve was not washed out. All seal nipple was in good condition, mark on bottom of seal nipple showed it had set on top of packer. Changed seal nipple and circulated sleeve and ran in hole with tubing changing gas lift valves on waý in hC?le~., Could not reach packer with same spacing as before. Respaced tubing with 8' pup. Landed tubing with 15,00011 on packer. Tested downttlbingwith 1000 psi, test OK. Pulled up 9' and changed over to di¢sel .downtubing. Pulled up and installed back pressure valve in tubing hanger. R~(~~ \J~'fj Rota.tedt~bingto get into packer . Tested tubing to 1000 psi. Removed RaE and flanged .Xri1astree. Tested seals with 5000 psi. ..:......~:.. J;." tubing to 5000 psi, OK. . DEC 2 1S~gged up Otis braided line to pull dunnny valve Out of storm choke. ÞMSJONOF ,t. ~ êÂ§ , ';(í _r'..¡·:~~,-~.4'"..t I:E·..·.:. ~u.;... rr';~ L ~ . ... ~ Mt. .JATHON OIL CD.MP.. .4'\1Y HISTORY OF OIL OR GAS WELL FIELD I I i DATE: STATE LEASE Trading Bay Uni t PARISH COUNTY BLOCK SEC. TWP. R. WELL NO. D-9 ELEV. fTOP OF OIL STRING . ELEV. MEASUREMENTS Top O.F Ro .T ARY.T ABLE _ ELEV. . TAKEN FROM GRD. OR MAT ELEV. It is of the greatest importance to hove a complete history ·of the well. Use this form in reporting the history of all important operations at the wen, together with the dates thereof,incl!Jding size of hole, size· and number of bits, complete description of casing, cementing, fishing or drilling difficulties, surveys, 011 tests, all completion operations and procedure, etc. HISTORY PREPARED By TITLE DATE 1968 WORKOVER .- REPAIR LEAKING CIRCULATING SLEEVE - Continued 10/17/68 PBTD 11,281' - Pulled dummy valve and circulated through ~n tubing. Ran Otis retriever for no go plug and pulled equalization valve out of plug. Ran in and latched onto plug and jarred on plug, jarred loose from plug. Ordered out new retriever and. made 7 runs for plug and jarred off plug each time. Could not retrieve plug. Released rig at midnight. Moved rig to D-13. Th)¡ef~R1'i&'[à n~ü -<.;:1:.111 J wi:l DEC 24 1q~P DIVISION OF on, AND 0.41 ANCHQtV>lJI ~ /~'\ ,~. f...i.·~ 41:.:4 REV. ::-63 f.hGE L DATE MARATHCN<DIL COMPANY HISTORY OF OIL OR GASlfWELL FI ELD LEASE Trading Bay Un} 1: PARISH COUNTY BLOCK SEC. TWP. R. WELL NO. »...9 STATE ELEV. [ToP OF OIL STRING· ELEV. MEASUREMENTS TO~OF ROTARY TABCE_ECEV. 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, (III tests, all cQmpletion operations and procedure, etc. HISTORY PREPARED By TITLE DATE 1968 . WORKOVER - REPAIR. LEAKING CIRCULATING SLEEVE - Continued 10117/68 PB¡D 11,281' - Pull~d~du..TDIl1Y valve and circulated through ~n tubing. Ran Otis retriever for no:~g2 plug and pulled equalization valve out of plug. Ran in and latched onto plug and jarred on plug, jarred loose from plug. Ordered out new retriever and made 7 runs for plug and jarred off plug each time. Could not retrieve plug. Released rig at midnight. Moved rig to D-13. ..... Jù}~'1:;:-:q'!m. .~ IJ1¡ü¡~~M vi! ~i6 DEC24 1965 blYlSlON OF on.. AND 0'" ANCHOiAGI ., .. ¿ . ". TRADING BAY UNIT D-9 PAGE 6 BIT RECORD Depth Depth Bit No. Size Make ~ On Off ~ H r Sa. Condition -- RR 17~ Reed YTA 325 420 Clean out piling RR 17~ " YT3A 420 660 240' 3 T4-B1 1 12~ lITC X3A 660 879 219 3% T2 '2 " If .. 87'9 1497 519 7 T3-B2 3 .. Hughes X3A 1497 2550 1063 9-3/4 T3 RRf/1 17% See HO, 650 1965 1315 12 HO 2 _17~ See HO 1965 2550 585 6-3/4 T2' 4 12~ IITC OSC 2550 3463 913 9~ T4-B4 5 tt Reed ST1AG 3'463 3534 7·1 2 Pull RR5 12~ II tf 3534 Dropped with fish 6 II Hughes X3A 3534 4414 880 10 T5 ~ 7 II " " 4414 5077 663 11\ 8 II Reed ST1AG 5077 5508 431 9 T5-B3 9 tI Globe ST3G 5508 6008 500 11~ T3-B4 -10 tI II ST3 6008 6727 719 16 T4 11 .. See S4tG 6727 7075 349 11~ T5 12 " Reed ST1AG 7075 7290 215 8 T6-B3 13 II See S4TG 7290 7593 . '303 11 T5-B5 14 tI IITC XDG 7593 7~65 372 13 T6-B2 15 It It XDG 7965 8271 306 14-3/4 T5-B2 16 tI tf tt 8271 8397 116 5-3/4 T7-B2 17 tf Reed ST1ÀG 8397 8558 161 6-3/4 T4-B2 18 II ; Globe ST3G 8558 . 8759 201 8~ T3 19 .. Hughes XDG 8759 9092 333 . 12~ T5-B2 20 tI Reed . STIAG 9092 9360· 268 10 T4-B2 21 .i Hughes . XDG 9360 9410 50 1 T3..B1 . 22 tI See S4TG 9410 9655 245 11 23, tI· u S4TG 9655 9877 222 11\ T6-B4 24 It . 9877 10,078 . 201 12~ T6-B3 IITC XDG 25 tI IITC ' XDV 10,078 10,326 248 16\ . T7-B3 26 tI " " 10',32q 10,372 46 4 T1-B1 27 12~ II . tI -10,372 10,632 260 17 T5-B4 28 .. " II 10,632 10,702 70 6% T4-B1 29 It Hughes' tI 10,702 10,802 100 6\ T5 30 12t " I II 10,802 10,854 52 6 T6 31 tI II XDR 10,854 11 ,024 170 16% T7 32 It It I! 11,024 11,217 193 18% T5-B4 33 II. Reed ST1AG 11,217 11,341 124 8% T5-B2 34 8\ IITC ODV 6964 11,281 4297 4 hrs ~ /--.. - '.t· D-~ TEST 12 G":Zone 14 - Z- J . ~ \,.í/,,..~.' .to }~ ~ ~ . tI .... J(I~~f:r . ·:'~~4:.;1"~· ~, dðG ,--1 ~ø2f/ D- 1;13 . /. DOLLY VARDEN PLATFORM DV-OIA .--"" } ~~,,' ". . . 05001 c-) o - '"'---- 2100 --- ----- I - ð o ò ,,:>\1 TEST #1 D- 7 TOTAL' OIL HR. '-I " ~" DATE' ~- ~'Î - ~~ ,,....\ I.· \ .}~..... . -.,..\'," , " \0 V'/ D- 9 RP D- ~ HR. 1 TOTAL' OIL TEST # 1 TEST 12 TEST 13 ;~~~n~ 4 01001 (Li'o 1 rdD I ¡tk d/r ' t/ , ~/:L .. "o~Ic:..., .0200'~I'~Ç d 7S I ~ ,:)19/ ~Lt.3 fêJ. ~ 03001tl~ &1) ~~ r-3 ~ I ..~ d- P / . & 1f' .'1~ d-I 04001S~ ~~- 'Ie 7~ / d. cO' ~'7 ~4 ~ 05001 16 1() ø ~ I S- I . 3J 3 /~t1 . J~" I'\-. 06001 ß~ Do 14 (, I 3t4 /3,1 . (p ~I (~ 07001 cA~ "61Q~ \ « t(<'t f l) ,k OBOOI/t\SlS___ . 9 39 J . .~~ 5 Ii / ð~" 0900v;ZI7ð'Ò ):)).~- / ~W::> ei~ /j() I , r ' 100 Ol~~ 3 ~ c),:)Z) / J ~;-:.~ (,~/ r .) /' ¿, 11 / / . L \;}.'-{I.( LIO 0' 4S '01 t\\l'J)(~ r:---' S < f.- . ~?L Lcl;) 2001/~oq1~S- )~ 9ÙJ - U,-; ÙÖ' /\ 'I 3001 \1 (\3Í) \(~ n~ - ll~" ~~ . t~~~ 400IA~¿'o /~1~~~) J¡c~9 r;;dJ /j/.7 ~ 5001Z.'~ "~{'liL - (')t¡L 3/6 /13' , JOOI,.:;};::L!Sr~ 1~~lò - t~ ~~ i0,oc:::.. k>3 700:;J~&h ;?\o99 - X~ r:l ,t~;- / èb '¡)UW\ ,~ 0. ~ , ~ .. 300 Z51Þ;& Zi'1 ßD ,-- -- rg ~ { "68 I I fJ'b 'OOIZ~~?,L '2.1 ¿ eö - tI6 I ~ I /b6 OOI2~c~z--Zd'g6 - trc I ' 113 I ,,/..to b OO~SC3;;l :i/!rlé'6 0-9.RD_ D-{ S'~( ¿~( /~ oolz-$i >32- 'L/ ~ 0 ~ ?:.rII J~{.., , JOlz 51ró3:'" , 'Z 11~ . () ~I 31 ~ I ~~ />' )01 5"~?~ .J ',~ r ;J~_~~ _dl'1~?J Õ OJ . .3~1 /~a , - ~ DATE . ~ .. d. ~ - ~ <c DOLLY VARDEN PLATFORM' DV-OIA ) ·--d.,.i" ", , .. .....\fi~. ...._ . . .~ ,.-., ;,·!.·~.I'r,j~~~~~~""- . I D- . . . q .~ " " ~ --L .' }. . D- 9. Q- ~ TEST 11 I TEST 12 TEST 13 G":Zone .t , Ó 0 ¡: ¿)' D . . 0 ð . CJ ," e;:!) þ , \ f.. ' .~ 1200 - 1300 :--r-----.-.- 1400 ~;!. :500 ~" l700 - .BOO ~ - 2000 - ~100 - l200 - 2300 - 1400 I 03001 04001 05001 06001 1100' 0- if 0200 0100 HR. I TOTAL OIL '1'/ ~" DOLLY VARDEN PLATFORM DV-OIA .-" (t::':l V·J ~~. v\ " ' ..,.....-" '. . .. ."..............'.. ..... . --.I FRIDAY 6 9 J2 :3 ~~ ~TIr=k¡-7~ ~. '-l~'~ ~ ~ ~ . ~t:::ê§ .J. ~.t -l-f.]~~ ~-=ì.:&~<~ ~ - - f;::::f::::t=e:=i=.[fJl j T~-!---.,.:: . .~::...~ ~ ti / ' , - :::=:~~i3:::-I-_~. t~ .,.?~..., ~ ìi~ c.::-,·,t:.I--t=- , h ...." " .-V:::~'/~ ~ ~ ~'--I.-----:..-.-I---I--1- ;É ,/ " Ä~'~^ ~ I ~ ¡--''1.-::::'--I-"~ --- , ~ ....>'-.. . '\ tS" /~' ' -- -- . Ci.-= '--c.-'~.T:-F ' '':¿ . '- .... \ '. 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TC=~ '__ / ~", \ }*\~~. - \ \ , \ \,\\:~-~~, '. ~~~F .H ~\ x~.:;W~O¡ \\ \, \ \, \ '-.;".\,z<;y~~~ T~'-h,=-E':Ef , '^/ # ---~\\~ \ ,Y~~~~~i:?:t. §ttg '~Ñ,' / //'Ç:;~'o~ I 'Î 'T-, c=--;..- r .-Im~t:::~f-'..... ;' ", ¡- c-= 1_ ~'r.=: f -! .-F-i-_r-:.+___:- -- / ¡' j ---L-...1-1--- / t / ./ / / ~. '- ) / ~<Q / ,~<f, ~~ ,,~ q / / /' / / / / / / /' A'o ~~ ~II I Ii '0 /' / q 'V .Þ~~ \\ ~ ..~ ~ð "V 'J..~. / / /' ,"~ > / ;, ~ ~ \~ '0 ~ c:- ;:;~ ~ ~ (t .-(~ ~ Q.r~".( oS ·L Z, ",. ~ ~ n......... ¡ ¡/ "' "~;T¡iž'ì¡j\- b t,\ o~ . k~Q\'\ _,'x' "'" - n 1 }, { .4 . ~ . ¡ f : .·I~, . ' 1 9 -- ........~.. 9 g v \; \ '\ \ "( JOB NUMBER AM7-1468 SURVEY BY ...- .......1. UTHO !IV EASTCO IN U. S. A. ~ ~'. SYMBOL OF SERVICE REPORT of SUB-SURFACE DIRECTIONAL SURVEY MARATHON COMPANY TSU D~7- WELL NAME COOK INLET, ALASKA LOCATION TYPE· OF SURVEY SINGLE SHOT ANCHORAGE ~ I·'" ú Ii, II ~ .~ t' J, .~ f j 1:; f :1 ¡i ,~ DATE JULY-AUG. ~ I~ !:~ '·'·1·'··'··... I' ~ 'fí; ¡ J J '/;': i OFFICE I ¡. JOB NO. Al'17-1468 DATE Julv and AUP.''Ust !968 CHECKED n. TRUE COURSE DRI" R I: C T AN G U LA ReO 0 R DIN A T I: . VERTICAL DEVIATION DIRECTION I I I DItf'TH NORTH .oUTH EAST WEST 20.00 1 535 JO 0°00' 535 00 0 00 0 30 I 2 158 2 650 :>0 0°00' 650 00 0 00 0 30 2 58 3 720 )0 2°1,. 719 94 2 75 s 71° E 60 02 4 773 )0 4°45' 772 76 4 39 s 55° E 3 12 3 62 5 804 bo 6°30' 803 56 3 51 S 46°E 5 .56 6 14 6 836 Do 7°00' 835 !2. 3 90 Ii 43 ° E 8 41 8 80 7 897 bO 8°00' 895 73 8 49 s 32° E 15 61 13 30 8 947 þo 9°15 ' 945 08 8 04 s 45° ß 21 30 18 99 9 997 Do 9° 45 · 994 36 8 47 s 50° E 26 74 2.5 48 10 1060 PO 10°1.5' 1056 35 11 21 S .51 ° .fi~ 33 79 34 19 11 1154 Do 11°15' 1148 55 18 34 s 49 ° E 45 82 48 03 12 1247 )0 12°15' 1239 43 19 73 s 51° E 58 24 63 36 13 1340 )0 13°15' 1329 96 21 32 S 49° E 72 23 79 451 I 1 ~) 14 1434 )0 15°00' 1420 75 24 33 s 49° E 88 19 97 81 15 1457 )0 15°15' 1481 53 16 57 s 50° E oR 84 110 50 / '; 16 1591 )0 18°00' 1570 93 29 05 s 50° E 117 51 132 75 17 1680 )0 20°00' 1654 56 30 44' s 49° ~ 137 48 155 72 18 180S )0 23°00' 1769 62 48 84 s 47° S >-170 79 ./ 191 44 19 1898 DO 25°15' 18.53 74 39 67 s 48° '~ 197 33 220 92 20 1997 DO 26°00' 1942 72 h3 40 s 4 7° ~ 226 93 252 66 21 2092 00 26°30' 2027 24 42 39 ~ 49 0 ~~ 254 74 284 65 22 2217 00 26°30' 2139 60 .55 78 Q 48° :" 292 06 326 10 U 'J 23 2373 00 26°45' 2278 91 70 22 S 49° ~ 338 13 379 10 24 2550 ' 00 27°45' 2435 56 82 41 S 4 7-° ~ 394 33 / 439 37 25 2680 00 28°30' 2549 80 62 04 S 49° E 435 03 11 486 19 1'0." NO. c:--aoap RECORD OF SURVEY it r. PORN NO. c--aoap JOB NO. jjv17-1h68 DATE July and I·uP'ust 1968 CHIICKED IIY. I I TRUE COURSI: Dftl" RECTANGULAR CQORDINATE. 8TATlON I MEASURED DRI" VERTICAL DEPTH ANGLE DEPTH DEVIATION DlRI:CTION NORTH IIOUTH lEAST I WEST 26. 2867 00 29°00' 2713 35 90 ~ S 48° E 49$ 69 553 56 27 3056 00 29-15' 2878 25 92 35 S 47° E 558 67 621 10 28 3244 00 29°15' ,3042 28 91 86 8460 E 622 49 687 17 29 3432 00 29°30. 3205 92 92 57 S 45° E 6$7 95 752 63 30 3588 00 27°30' 3344 29 72 P3 S 59° E 725 05 814 31 31 3682 00 29°00' 3426 50 45 ~7 s 59° E 748 52 853 43 I I I "- 32 3904 00 29° 45 · )619 24 110 P-6 s 57° E 808 51 945 82 33 415.5 00 31°001 3834 40 129 Þ.7 s .58° E 877 01 ,,/ 1055 44 34 4414 00 31°45' 4054 24 136 ~9 s 57° E 951 23 1169 75 35 4606 00 31°00' 4218 82 98 88 s 56°E 1006 52 1251 72 36 4826 00 30°00' 4409 3L. 110 pO C' S40 n 1071 18 1340 71 0..) ti.. 37 5077 00 28°301 4629 92 119 78 S 51° E 1146 56 v' 1433 79 38 5273 00 28°30' 4802 16 93 53 s 51° E 1205 42 1506 47 I 1 ~) 39 5492 00 29°00' 4993 70 106 17 s 51° E 1272 23 1588 S; 71 40 5695 00 29°30' 5170 39 99 96 S SOoE 1336 48 1665 54 41 6008· 00 30°00' 5441 45 156 50 S 48° E 1441 19 1781 84 42 6227 00 30°15' 5630 62 110 33 S 48°s 1515 01 1863 83 43 6507 00 29°45. 5873 72 138 ~4 s 46° E 1611 .53 1963 77 b.h 6726 00 28°45' 6065 72 105 34 s 4.5° s 1686 02 2/:>3'8 2~ 45 7038 00 27° 30 I 6342 If.., Ih4 05 E) ~5 0 ~ 1787 88 ./ 2140 12 1.16 7290 00 27° 30' 6565 98 116 35 s 44° ~ 1271 57 2220 95 47 7593 00 26°30' 6837 13 135 ~o s L.2 0 ~~ 1972 OL. 2311 l.¡l 48 7965 00 24°00' 7176 9S 151 ~9 S 440 E 2080 86 2416 51 49 8271 00 23°00' 7458 62 119 ß5 s 43° S 2168 30 2498 04 50 8558 00 220 45 · 7723 29 110 ~8 S 43° S 2249 47 2573 73 RECORD OF SURVEY ", POIUII NO. C>-8OaP JOB NO. Atvf7-1468 DATE July. and j~ugust 1968 CHIECKKD IIY. TRUIE COURSIE DRI" RECTANGULAR COORDINATES _AnoN. MEASURED I DRI" I VlERTlCAL DEPTH ANGLE DEPrH DIEVlATION DIRECTION NORTH eoUTH lEAST WEST 51 8757 00 25°15' 7910 45 84 9 s 44° E 2310 53 Ý2632 70 52 9092 QO 2,°30' 8212 82 144 2 s 43P E 2416 01 2731 06 53 9360 00 2,·00' 84,S 71 1136 5·42° E 2.500 17 2806 84 54 96f:J:) 00 24 °)0' 8721 67 124 1 s 41° E 2594 31 2888 78 55 9877 00 25·00' 8918 34 91 70 S 40° E 2664 .56 V 2947 72 56 10078 00 26.00' 9099 00 88 s 41° E 2731 06 3005 54 57 10326 00 27°30' 9318 98 114 s 40° E 2818 77 3~q 15 58 . 10372 00 t8°00' 93,9 59 21 s 40° E 2835 32 v 3093 03 59 10632 00 2 7° 30 · 9590 21 120 S 40° E 2927 27 ;31 70 19 60 11024 00 34°00' 9915 18 219 s 41° E 3092 71 3314 01 61 I 11217 00 32°001 10078 84 102 27 S 40 ° E 3171 05 3379 75 62 11341 00 32°00' 10183 99 65 71 s 40° E 3221 38 v' 3421 99 I 1 I I I I I I I I I ~) I I I CLOSURE I 4, 700.0[7 ~ s 143° I 161 E RECORD OF SURVEY ... ., ·..~ ...-.,. cß iiJ ~-4 '" "--,_iW' Form No. P--4 '" REV. 9-:iO-67 ~\ P. ç. .\', \ ~ . ~ / SUBMIT m C T!:l ~.. R t \..~ '. t . S. API Nm,1:ERlCAL CODE OIL AND GAS CONSERVATION COMMITIEE .~ ... .. .\ 50-133-20131 6. LEASE DESIGNA nON AXD SERIAL NO. "".IJ"1ERþ..\..~ . 0-:' to ADL 18729 '\S\ON '- \ --HORN 7. IF INDIA~ ALOTTEE OR TRIBE NAME STATE OF ALASKA MONT'HL Y RE;PORT O'FDRILLlNG AND WORKOVER OPERATIONS 1. OIL rvl GAS 0 WELL Iå..I WELL OTHER 2. NAME OF OPERATOR Union Oil Com an of California* 3. A DRESS OF OPERATOR 8. UNIT F A1U1: OR LEASE NAME Trading Bay Unit 9. WELL r\O. 2895 Denali Street, Anchora e, Alaska 99503 4. LOCATION OF WELL D-9 (42-7) 10. FIELD A..~D POOL. OR WILDCAT Surface: 761.3' N, 1131.5' E from SW Corner Sec. 6, T8N, R13W, SM Top of Hemlock: 1980' S, 660' W from NE Corner, Section 7, T8N, R13W, SM McArthur River 11. SEC., T.. R., M., BOTTOM HOLE oBJECTIVE} Sec. 7, T8N, R13W, SM 12. PERMIT NO. 68-62 13. REPORT TOTAL DEPTH AT END OF MONTH, CHA..~GES IN HOLE SIZE, CASING AND CEMENTING JOBS INCLUDING DEPTH SET AND VOLUMES USED, PERFORATIONS, TESTS AND RESULTS. FISHING JOBS. JUNK IN HOLE AND SIDE-TRACKED HOLE AND ANY OTHER SIGNIFICANT CHANGES IN HOL]¡; CONDITIONS. Trading Bay Unit D-9, August 1968 8/1 Drilled plug and float collar and tested casing to 1500 psi, held OK. Drilled out shoe and drilled 12-1/4" hole to 34631. 8/2 - 8/21 Directiona11ydri11ed 12-1/411 hole to 11,217'. Hole angle 32°, direction S 40° E, total vertical depth 10,078, S 3178 E 3380, distance 4636. Drilled 12-1/4" hole to 11,3411. Conditioned hole to run logs. Ran DIL 1atero10g. 8/23 Ran Gamma Ray Density log, sonic caliper log and dipmeter. Conditioned hole to run casing. 8/22 8/24 Ran 270 joints 9-5/8" casing, landed at 11,3271 with float collar at 11,281' and DV collar at 6,966'. Ran 500 gallons mud sweep, 727 sacks Class G cement with 6% gel, 0.5 R-5 mixed in 122 bb1s salt water, 600 sack neat cement withO.5 R-5 and 0.8% D-31 mixed in 72 bb1s of fresh water. Displaced and bumped plug with 2000 psi, opened DV tool, conditioned mud, ran 500 gallons mud sweep, 1148 sacks Class G cement with 6% gel mixed in 230 bb1s salt water, followed by 100 sacks neat cement with 2% calcium chloride. Displaced and shifted DV tool. 8/25 Tested BOP with 3000 psi, held OK. Testing casing with 2000 psi, held OK. Drilled DV collar, tested casing with 2000 psi, held OK. Cleaned out float collar at 11,281', tested casing to 2000 psi, held OK. 8/26 Displaced mud with 758 bb1s of diesel fuel, change of orders and redisp1aced diesel with mud. Conditioned mud four hours.., rann cement bond log and gamma ray correlation log, cemen~nd checked oK:) ~ '",,-- /",,/J I,...__~~_.._...I __..~ _...._...\ /'"' f; '\ -'. "'""'- Form No. P-4 REV. 9-30-67 STATE OF AlASKA SUBMIT IN DUPLICATE f"~ OIL AND GAS CONS·· ERVATIO·N CO·MMITTEE ~ ~ , \<" ;, ~ r C \ \¡ \. v' 5. 'API Ntr.VIERlCAL CODE MONT'HL Y RE:PORT O'FDRILLI AND WORKOVER OPERATIONS 50-133-20131 6. LEASE DESIGNA nON AXD SERIAL NO. 1. ADL 18729 5 7. IF INDIAN', ALOTTEE OR TRIBE NAME OIL rvl GAS 0 WELL LAJ WELL OTHER 2. NAME OF OPERATOR 8. tJ.NIT, FARM OR LEASE NAME 2805 Denali Street, Anchorage, Alaska 99503 4. LOCATION OF WELL D-9 (42-7) 10. FIELD A.."1D POOL, OR WILDCAT Surface: 761.3' N, 1131.5' E from SW Corner Sec. 6, T8N, R13W, SM McArthur River 11. SEC., T., R., M., BOTrOM HOLE OBJEC'I"IVFJ Top of Hemlock: 1980' S, 660' W from NE Corner, Sec. 7, T8N, R13W, SM Sec. 7, T8N, R13W, SM 12. PERMIT NO. 68-62 13. REPORT TOTAL DEPTH AT END OF MONTH, CHA..."1GES IN HOLE SIZE, CASING AND CEMENTING JOBS INCLUDING DEPTH SET AND VOLUMES USED, PERFORATIONS, TESTS AND RESULTS, FISHING JOBS, JUNK IN HOLE AND SIDE-TRACKED HOLE AND ANY OTHER SIGNIFICANT CHANGES IN HOU¡: CONDITIONS. Trading Bay Unit D-9, August 1968, Page 2 8/27 Perforated from 11,1101 to 11,1421 and 11,078' to 11,1101, Induction log measurements. Ran DST 11, set packer at 11,0481, initial flow 5 minutes, initial shut-in 60 minutes, final flow 305.minutes, final shut-in 420 minutes. Strong blow on initial flow, strong initial blow on final flow, decreasing to fai rafter 3 hours, poor after 3-1/2 hours and through remai nder of t1 ow. No gas or liquid to surface, reversed out 11 bb1s fresh water cushion mixed with 14 bb1s of heavy black oil, 23.2° API gravity and 18 bb1s mud cut oil estimated at 60% oil 40% mud. Cut on oil sample 29.7% water and 0.3% emulsion, water salinity 425 ppm. Unseated packer and pulled out of hole. . 8/28 Finished pulling out of hole, recovered 60' rat hole mud with 10 gallons sand above DST valve, recovered small oil cut mud sample of fluid from valve, fluid contained 35% oil and 65% mud emulsion. DST pressures inside chart, IHH 4932, ICIP 4069, IFP 623, FFP 909, FSIP 4021, FHH 4932; outside chart, IHH 5221, ICIP 4089, IFP 628, FFP 914,:FSIP 4041, FHH 5583. Ran in hole with drill pipe, rigged up perforators and ran gauge ring, ran 9-5/8" permanent packet and set at 10,5121 with tail pipe at 10,5451. 8/29 Ran 322 joints 4-1/2", 13.6 .. N~80 tubing, landed in packer at 10,512'. Removed BOP and riser, flanged up Xmas tree, tested tree to 5000 psi, rigged up perforators and displaced mud in tubing with diesel fuel. 8/30 Closed circulating sleeve, tested to 1000 psi on casing for 30 min. OK . Perforated with 2" Slimcone gun, 4 holes per foot 11,030' - 10,918, 10's8981- 10,8681, 10,846' - 10,822', 10,798 - 10,7281, 10,628' - 10,596', 10,678' _ 10,712'. Released rig at midnight. . * Marathon Oil Company, Sub-operator, Dolly Varden Platform. SIGNED TITLE Di at" ll'rl g ~l1r...t"ñ DATE Q/l0/f.A . 14. I hereby certify NOTE-Report on this orm is required for each calendar month, regardless of the status of oper n with the Division of Mines & Minerals by the 15th of the succe~ding month, unless otherwise directed,' SEP 1> G. ~ ,. DIVISION OF lvIII-lie< " AI"¡('¡-"" n> .1ae1.... &Yn..y l'arl L. VOt1c1e.rAbe ......hDladaear .ur tr:u1,. ~. .. ./." am,. B. .1.· -raU8J" ..Ukt DrUl........f"4.t.....t "'·01'1 <:...,.f ~Jtf.mk aos ...ø Awe. ......... AJ.ø- .sa1 .... ,1:1.-; Bad__ 18 7.. ."..... ~ dl~.tiH ...., '.1' the ..... ........ _11. ....t 19. 1.. ... -r...... lay Vatt D-' ....11. eo.,.., ., £a1ifcmala. Optmtter ~ OIL AND GAS CONSERVATION COMMITTEE MONTHL Y REPORT O'F DRilliNG AND WORKOVER OPE¡RATJONS 5. API NU:VIERlCAL CODE 50-133-20131 'b ¡,/ P]j/ -""'" Form No. P-4 REV. 9-30-67 STATE OF ALASKA SUBMIT IN DUPLICATE 6. LEASE DESIGNATION AXD SERIAL NO. AOL 18729 1. OIL rvl GAS 0 WELL LAJ WELL OTHER 2. NAME OF OPERATOR Union Oil Company of California* 7. IF INDIAN: ALOTTEE OR TRIBE NAME 8. UNIT,FARM OR LEASE NAME 4. LOCATION OF WELL 3. ADDRESS OF OPERATOR 2805 Denali Street, Anchorage, Alaska 99503 Surface: 761.3' N, 1131.51 E from SW corner Sec. 6, TBN, R13lV, SM 0-9 (42-7) 10. IELD A..'"'1D POOL. OR WILDCAT Top of Hemlock: 1980' S, 660' W from NE Corner, Section 7, T8N, R13W, SM r-tcArthur River 11. SEC" T., R., M.. BOTr'OM HOLE OB.TEc"rIV¡;) Sec. 7, T8N, R13W, SM 12. PERMIT NO. 13. REPORT TOTAL DEPTH AT END OF MONTH, CHANGES IN HOLE SIZE, CASING AND CEMENTING JOBS INCLUDING DEPTH SET AND VOLUMES USED, PERFORATIONS. TESTS AND RESULTS. FISHING JOBS. JUNK IN HOLE AND SIDE-TRACKED HOLE AND ANY OTHER SIGNIFICANT CHANGES IN HO~ CONDITIONS. Tradtmg Ba~ Unit D-9, July 1968 7/26 - 7/27 Moved rig to conductor #5, Leg A-2 and rigged for drilling. 7:30 a.m., 7-27-68. Cleaned out piling from 325' to 420'. Sun Gyro from surface to 420'. Spudded at Ran Sperry 7/28 Drilled 17-1/2" hole with turbodrill from 420' to 660'. Gyro Survey showed 0-3 and 0-9 piling close to each other at 420'. Ran turbo drill No.1, faced S 54° E at 660', drilled to 791'to 879', hole turned from S 56° E to S 32° E. 7 /29 Conti nued dri 11 i n9 wi th turbo dri 11 No. 2 from 879' - 978 I, turned ho 1 e from S 32° E to S 50° E. Drilled 12-1/411 hole to 2240'. 7/30 - 7/31 Drilled and surveyed 12-1/2" hole from 2240' to 2250', opened 12-1/4" to 17-1/2" hole from 650' to 2027', circulated 1-1/2 hours. Repaired 411 mud line. Ran 62 joints 13-3/8" 61# J-55 buttress Range 3 casing) 2481.47', set at 2530.97' with Baker differential fill shoe and collar, set 44.80' below rotary table, circulated hole, and cemented casing with 2000 sacKs Class G with 6% gel, mixed with Inlet wate~ and 400 sacks Glass G mixed with fresh water. Bumped plug with 1500 psig, held OK, good returns to surface. RECEIVED * SUb-operator, Marathon Oil Company, Dolly Varden Platform. r\ ' ' ,', 1 r> 10Ç;8 f\U I.:; ..'; ,d" ON OF M)1'»fS & MINERALS DIVIS I ..' ANCHORAGE SIGNED e and correct D1st. Drill1q Superineendent TITLE DA'l'E 8/13/68 14. I hereby certify NOTE-Report on this to m is required for each calendar month, regardless of the status of operations, and must be tiled in dup/icatt with the Division of Mines Minerals by the 15th of the succeeding mo nth, unless otherwise directed. Form P-3 REV. 9-30-67 /........... Submit "Intentions" in Triplicate & "Subsequent Reports" in Duplicate STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE 5. API NUMERICAL CODE 50-133-20131 }( {tI IL- 6. LEASE DESIGNATION AND SERIAL NO. SUN'DRY NOTIC'ES AND REPORTS OoN WELLS (Do not use this form for proposals to drill or to deepen or plug back to a diffierent reservoir. Use "APPLICATION FOR PERMIT-" for such proposals.) ADL 18729 1. 7. IF INDIAN, ALLOTTEE OR TRIBE NAME OIL rv1 GAS 0 W,ELL LA.! WELL OTHER 2. NAME OF OPERATOR 8. UNIT,FARM OR LEASE NAME Tradin Ba Unit 9. WEl.tL NO. Un; n Oil Com an of Ca1ifomia* 3; ADDfŒSS OF OPERATOR 2805 Denali Street .. LOCATION OF WELL Alaska 99503 D..9 At I>urface 756.41 N.. 1138.51 E from SW corner. Sec. 6. TBN, R13W. SM. Top of Hemlock - 1,9801 S, 660' W from NE corner, Sec. 7, TaN, R13W, SM. 13. ELEVATIONS (Show whether DF, RT, GR, etc. . 7 12. PERMIT O. I 68-62 Check Appropriate Box To I!ndi'cate Niat'ure of Nlotice,Report, or Other 'Data SM 14. NOTICR or INTENTION '1'0: SUBSEQumN'1' RmpORT or: TEST WATER SHUT-orr ~ PULL OR .ALTER CASI:'>'G ~ w.... SHUNn B .,,,,.,,. wm II FRACTVBE TREAT _ MULTIPLE COMPLETE _ rRACTURE TBICATKICNT ALTERING CASING SHOOT OR ACIDIZE _ ABANDON- _ SHOOTING OR ACIDIZING ABANDONMICN'T- RI!:PAIR WELL CHANGE PLAlJS (Other) (Other) CO· rr· ect to· D O. f H.' eml oc·k 1 0.· C - (NOTE: Report results of multiple completion on Well _ · . ' Completion or Recompletion Report and Log form.) 15. DESCRIBE PROPOSED OR COMPLETED OPERATIO:'>'S (Clearly state all pertinent details, and give pertinent dates, including estimated dat~ of Itarting an3' proposed work. . , . . To correct erroneous top of Hemlock location ~iven on "Sundry Notice and Report on Wells" dated 7/1.?/68. RECE\VED I c" 1 c;. 11ì (;5) [,.\ t) tJ 1;-.".-;' 1 ~-) ~,. ,j \. *Marathon Oil Compan; --'Sub-operator \ 'cs 8. MINERALS ISION OF MI.'-!c _ DIV (ANCHORAGE SIGNED ue and correct 16. I hereby eertU¡ tb -Dist. Drilling Supt. TITLE DATE BI3/68 (Thi, ,pace for State oflice use), ,.i/'//;~/ . [_ .. ..J' APPROVED BY ¿f{ /' t? lr',v~ -l./~ [<./ '·-':"""""--TITLE CONDITfONS O~" APPROVAL, II' ANY: '_I: //( /', ,r-¿' ></ ' DATE éJ ' /,f· (. J See 1'nstrucfions On Reverse Side .l:: ~ ~ MARATHON OIL COMPANY PRODUCTION - UNITED STATES AND CANADA P. O. sqx 2380 ANCHORAGE. ALASKA 99501 July 31, 1968 State of Alaska Department of Natural Resources Division of lands 344 6th Avenue Anchorage, Alaska Re: ADL-18729 Oil and Gas Lease Gentlemen: In accordance with Paragraph 21 of the subject oil and gas lease, Marathon Oil Company as sub-operator hereby advises you that Well No. 0-9 was spudded July 27, 1968 from the Dolly Varden Platform. The surface location is 756.4'N, 1138.5'E from Southwest corner Section 6, T. 8 N., R. 13 W., S.M. and the proposed bottom hole location is 2,200'S,400'W from Northeast corner Section 7, T. 8 N., R. 13 W., S.M. Very truly yours, MARATHON all COMPANY ~~~~ <<--..·è,· ~;:;is L. Lowman District Landman -r- Ml L : 1 j cc: R. T. Anderson - Uniqn Oil Company Operator of Trading Bay Unit RECE1VFO AUG 6 1968 DIVISION Of MINES & MINERALS ANCHORAGE ---,--.~---- .---- ------- ,~ r- ¡a! -'r-- ~J'·16. 1968 ..; t'ad18a.., Utd.t Ð-9 ..... Oil ~, of Ca11fo""a. Ofn'atn a... L ·Sd'" "Cd_adJ'... Iup.t:a"'., ..... out 11·1., er· C&lU.ada .., ..lIlt. It.. ~...... .., BeutIf,;'If: 1Iw'108ú .. ,... ........ ." of .....,..tla (It-) fer .. .... ·r....... well. ...,. CBI., ~. ./ "':/ .,~.. ÞrlL. Y_i_Ahe htøl_lq1aeer ILY =M.)" "1on~ STATE Of ALASKA OIL AND GAS CONSERVATION COMM,ITTEE 5. API NUMERICAL CODE ~ It ~ ~: rtJ ~. Form P-3 REV. 9-30-67 /"-"./-'. Submit "Intentions" in Triplicate & "Subsequent Reports" in Duplicate . SUN'DRY NOTICES AND REPORTS ON WELLS (Do not use this form for proposals to drill or to deepen or plug back to a diffierent reservoir. Use "APPLICATION FOR PERMIT-" for such proposals.) ADL 18729 1. 7. IF INDIAN. ALLoTTEE OR TRIBE NAME OIL GAS D WELL WELL OTHER 2. NAME OF OPERATOR Union Oil Com an of California* 3. ADDRESS OF OPERATOR 8. UNIT, FARM OR LEASE NAME Tradin Ba Unit 9. WELL NO. 2805 Denali St., Anchora e, Alaska 4. LOCATION OF WELL At. surface Or1 g1 na 1 761.3' N t 1131.5' E from SW corner Sec 6, TaN, R13W, SM. Amended 756.4'N, 1138.5'E ~~2To~~ ~g5gefro~§ YinJ~N66fi13¥rJM£ lTgg gtc 5, D-9 Sec 7, T8N, R13W, SM 12. PERMI NO. ,.. 68-62 Check Appropriate Box To .indicate Nature of N~tice, Re'pørt, or Other ·Data 14. 'þ, " /. " I \I¡ TEST WATER SHUT_o::TI~CJD OT (NTON:U:: : :ALnR CAR"O 1.1 wmR RHU'~" auøO~N' ..roOT :::.....0 W'LL I~i\ FRACTURE TREAT MULTIPLJD COMPLETE FRACTURJD TBB:ATKJDNT ALTERING CA.SING ' 0.00. OR ACtO'" AOANDON' OHOG'''O OR ACtD("NO - "ANDON"...' = \.\ REPAIR WJDLL CHANGBI PLAJlTS (Other) \ ' (NOTE: Report results of mUltiple completion on Well \ (Other) Com letion or Recom letion Report and Lo form.) . 15. D¡';SCRIBE PROPOSED OR CO~tPLETED OPERATIO~S Clelll'ly state all pertinent details. and give pertinent dates. including estimated datI! of st.rting an~: proposed work,·' Changed slots in leg to better fit our directional program. Original application for Permit to Drill was applied for on Well D-9 (42-7) using Slot 3 surface location 751.3'N, 1131.S'E from SW corner See 6. TaN. R13W. S~1'. would nowreq~est to amend Permit for Slot 5, 7S6.4'N, 1138.5'E from SW corner See 6. ':\ \. .\ ., J R E ( EI V f D JUt... 15 1968 DIVISION OF MINES & MINERALS ANCHORAGE *Marathon Oil Company - Sub-Operator SIGNED l/:!t\triet ])r111181 SuperintenâentDATE 7/12/68 (This space tor State o1li~e use)/ '" /¡;... /I IJ ¿71/ "X·· '//Í.. ,,-,~e·'~ --cv~-/ APPROVED BY /t ( " " i CONDITIONS OF APPROVAL, IF ANY: TITLE ....) 12 ,/ } /{.Á.- f ~..--..---y,~ (/ DATE - / _/ / ..,. See l!nstrucfions On Reverse Side Bltd.N.- ..:~ .~ R. .....11. Jr. '''1eahpervtaor veq aul,.,_ø. "1_..J-~fJad .... ."..... ..,lieact_ for pead.t .. 4nll 6e~"'.IU". ...n. Vel1..,1_..... eIdpa ...'aot ......... ..-. ....,....t_tA _.ea.u. Laai. *1F~.. 1t4...I.~rnW.Jn'- 0.11:..... 2.$ ......'1 ..... ......... Aløk. .., Dear S~I'. ~dy3. 1968 Ie. T.......,· 11.. .»-9 ....... Oil C....., of Ca1tftmda. OpeÞter _.WI ·1_ _lIm·Jllfl_..... IIIJIß$. ..1S....... ...... ..tdU. . I..... ....... . ..,t sa .. ·.'_1 ...,... f. ...... .... "'-" ~ .., Vaü·... .. . ....... .... OUft... r ljJ ., Cdt.I . ........ SUBJECT: ~ TI - ....ai 1 ~11.h. ..1:..1 T.·..'·. 1· U II.... ..... '. - DATE '- ...IIs. "11_ _........ mALl State of Alaska FROM: TO: r MEMO'RANDOM /....-:, /~ FORM SA,IB 125.5M 8/67 FORM SA-1B 125.5M 8/67 ..-...... MEMO'RAN'D:UM TO: r FROM: --- State of Alaska ..... .. ... ØD1IØIU" .. B. ."111 ._1J..id. ..,.., In,...'.. ."111111.. .. ....... IM-··· n g·L ".itlt.,'-. .........'J...... DATE ad.r S. 1161 SUBJECT: __ilia -,8d& ... .... on ~llll J _ ., CdtI..t.. "1.-- ..nl'lI..l1Ift ... .."., .. ...,.Il. lid lI,lte.d- .. ØUJ. ... De ..U~. ·l1IJ..dl8JllwIt.. -... .....1'1...... (Ø\ ~~.,,~ ... STATE OF ALASKA OIL AND GAS CONSERVA.TION COMMITTF-f API 50-133-20131 IC lei 'o!r1f:} ~ /...-....,; Form P-I REV. 9-30-67 SUBMIT IN TRIl ATE (other instruction!> tin reverse side) 5. 1a. TYPE OF WORK APPLICATION FOR PERMIT TO DRILL, DEEPEN, OR PLUG BACK DRILL [] DEEPEN 0 PLUG BACK 0 SINGLE rXJ ZONE ~ 6. LEASE DESIGNATION AND SERIAL NO. ADL 18729 . IF INDIAN, ALLOTTEE OR TRIBE NAME b. TYPE OF WELL OIL (Tl GAS 0 WELL ß..J WELL 2. NAME OF OPERATOR OTHER MULTIPLE r;:-l ZONE L.J 8. UNIT~FARM OR LEASE NAME Trading Bay Unit 9. WELL NO. Union Oil Company of California * 3. ADDRESS OF OPERATOR 2805 Denali Street, Anchorage, Alaska 99503 4. LOCATION OF WELL Msurlaœ 761.3'N, 1131.5'E from SW corner Sec 6, At proposed prod. zone Top of Hemlock, 1980'S 660'W Sec 7, T8N, RI3W, SM 13. DISTANCE IN MILES AND DIRECTION F.1.0M NEAREST TOWN OR POST OFFICE* RI3W, SM NE corner D-9 (42-7) 10. FIELD AND POOL, OR WILDCAT McArthur River 11. SEC., T., R., M., (BOTTOM HOLE OBJECTIVE) Sec 7, T8N, RI3W, SM 12. '. - "- ..,' .' ,,-", -,-, 21 miles NW ofK,~ñai"Alaska 14. BOND INFORMATION: Statewide United Pacific Insurance TYPE Surety and/or No. 15. DISTANCE FROM PROPOSED* LOCATION TO NEAREST '..... ...... PROPERTY OR LEASE LINE; 'FT. ' (Also to nearest drig, unit, if any) 18. DISTANCE FROM PROPOSÉI> LOCATION ~~ :::~~~~~ ~~Ip~~ILLING'SPN~LET.JFI>. $100,000.00 16"iNO:'OF ACR~ IN LE.A:SE Amount 17. NO.: ACRES ASSIGNED TO THiS WELL 'r60~00 2ð. ROTARY OR CABLE TOOLS ßotary 116.00 RT MLLW Jul 12, 1968 23. " PROPOSED ·CASING AND· CÉMENTING PRÖGRAM ' ~ ., c. WEtGH-tPER'É"OoT SIZE OF HOLE SIZE OF CASiNG~ GRADE: :1 '£,SmINd·D:ItÞriI QUANTITY OF CleMEN';: 17~" 13-3/8" 61# 3-55 2500 2400 sat'ks 3sÓI" h,1.1.;¥- 12~" 9-5/.8" 40, .4.3. 5,4,7Jt N-80 '.' 9!70-0 2600 sacks q/¡Jo FtI/",û I 8!s" 7" liner 29#. N~80 11.160 350 sacks ~oð C> ' F~·II'... () . > , I . .. Install 20" Hydril, 'k:ìIlline'and choke manifold prlor toconunèncement of drilling. Drill 17~" directioWål:hb'le:Vtb'2500 "'. Runand;'cemeht13-3/8" casing to 2500'. Install and test BOPE with 3000#. Drill 12~" directional hole to 9700'. 'Run and cement 9-5/8" casing to 9700'. InsJ(l11éìAdte~tJ3.0PJ;~ DriJI 8~" directional l}ole to 11,160'. Run and 'cement 7" lil1~r ~p:to;t;G,tl dep.;t:p.r ,Complyteforpr,oç1uction. Bottom hole location - 2,220' FNL and 400' FEL, Sec 7, T8N, RI3W, SM * Marathon Oil Company, Sub-operator, Dolly Varden Platform IN ABOVE SPACE DESCRIBE PROPOSED 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 direcLonally. give pertinent data on subsurlace locations and measured and true vertical depths~ ~iveblo:wout preventer program. DATE July 1, 1968 TITLE District Land Manager SAMPLES AND CORE~, R~WR1ID o YES ~ NO I DIRECTIONAL SURVEY REQUIRED OF APPROVAL, IF ANY: OTHER REQUIREMENTS: A.P.I. NUMERICAL CODE ;7'YES o NO So - I 3 ~-¿ 6 I :3 PERMIT NO (þ ~ (:,1- , (k., I< vItt ~ h APPROVAL DATE THOMAS .R. MARSHAll, :m. > TITlJ.xecutive Secretary *s.. Instructions ~'~~.~è Si~s \..Onservation Committee APPROVED BV PATE 7/:3 /'8 . I , JUNE, 1968 o SCALE: 1"= 2000' ~-- WELL LOCATI'ON MAP MARATHON SUB-OPERATOR TRADING BAY STATE 0- 9 (42 - 7) J7 J8 UNION I 1 " ! '\ 0-8 (24-8) ¡ -t 0 U-M AOL 18729 I _ _.__._..____..___n..__ __ _._,__ ....._ __ _ .._n______.._ __ ~ PPSS AOL 17579T~ I + N 9 .......... ..........'0 0-12 8(22-8) --0-5 - ----- ------.-- ---- .~~ (24-6) " ...... " ........... " ...... " " " ,-, , , " ' " , , " '"'- '-,-"- " Prop. Top HemlOCk~ TMD 10,480' )\,. 0 - 9 -¡VD 9,450' 'd ~2 _ 7) PIi,.HL TMD-..II,160' , TVD 'S,,090 "- '\ "- '\ "- " ........... --t- 0-4 _______-0 - - - -(24-5)- i .. + 1 I ...... ..... ...... ...... ..... ....... ...... ..... ..... .......... + -+ ! 4 ,-' .J 0-1 (34-32) 0-11 9 (14-32) I I I I 0-10 (44 -5) ..11 0 ~'~--.1 8 "0::. 7 ,.'0...... 6 ''O_'''O~''_4 3 Z <.>- -'--0"---0.'_-0 0-2 (22-5) 0-7 P (/4-33) / / AOL 17594 I ,// r~ / / / / / / / / / D-3 (42- 6) / TO 1/,281' I R 13 W T8 N R 13W T9N J 3Ll. -) ~, 00 32 /~,- ~ NOTICE The following well logs and oversized documents have been placed in offsite storage. If you would like to view the original documents, please contact the AOGCC librarian. AOGCC 3/4/2005 l} ;rt{ 05 ;..' '; "1 ,".;lr~;:li~¥D!~!tY.ï~\;'·I~\~'C;i~f~':J~t.o.il~~.~;'¡',~I-..~II.'IiI:1",,\"1!<N'~~'I""'1.,;,..'''''; ,1~,ICIJ..;I,...I:,..,::~i~:;'¡,',¡,."".~""~;.",,.. ,". 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