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Home My WebLink About176-079 ' q / o BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB-20 Post Office Box 196612 Anchorage, Alaska 99519-6612 tq;Y 1GL i E 201': July 6, 2011 Mr. Tom Maunder I - oriq Alaska Oil and Gas Conservation Commission 0,0 333 West 7th Avenue Anchorage, Alaska 99501 Subject: Corrosion Inhibitor Treatments of GPMA Niakuk Dear Mr. Maunder, Enclosed please find multiple copies of a spreadsheet with a list of wells from GPMA Niakuk that were treated with corrosion inhibitor in the surface casing by conductor annulus. The corrosion inhibitor is engineered to prevent water from entering the annular space and causing external corrosion that could result in a surface casing leak to atmosphere. The attached spreadsheet represents the well name, API and PTD numbers, top of cement depth prior to filling and volumes of corrosion inhibitor used in each conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10-404, Report of Sundry Operations. If you require any additional information, please contact me or my alternate, Mehreen Vazir, at 659-5102. Sincerely, Gerald Murphy BPXA, Well Integrity Coordinator • • BP Exploration (Alaska) Inc. Surface Casing by Conductor Annulus Cement, Corrosion Inhibitor, Sealant Top -off Report of Sundry Operations (10 -404) Niakuk Date: 05/15/11 ' Corrosion Initial top of Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name PTD # API # cement pumped cement date inhibitor sealant date ft bbls ft na gal NK -01A 1780280 500292015801 P&A 3/9/91 NA NA NA NA NA K -02A 1780790 500292018001 P&A 3/13/91 NA NA NA NA NA NK -03 1780940 500292035000 P&A 4/14/80 NA NA NA NA NA NK-04 1842000 500292121700 P&A 4/14/96 NA NA NA NA NA NK -06 1850270 500292129000 P8J14/15/98 NA NA NA NA NA NK-06 1852780 600292148800 P&A 4/15/98 NA NA NA NA NA NK -07A 2010630 500292241001 0.2 NA 0.2 NA 0.9 4/30/2011 NK-08A 2010290 500292249101 0.2 NA 0.2 NA 0.9 4/30/2011 NK-09 1941400 600292251800 2.1 NA 2.1 NA 17.0 4/30/2011 NK -10 1931840 600292242500 1.5 NA 1.5 NA 11.9 4/30/2011 NK -11A 2020020 500292278901 1.5 NA 1.5 NA 11.9 4/30/2011 NK -12C 2030550 600292241403 1.8 NA 1.8 NA 31.0 4/30/2011 NK -13 1961340 500292269300 2.3 NA 2.3 NA 22.1 5/4/2011 NK -14A 2080310 500292266801 1.8 NA 1.8 NA 17.0 5/4/2011 NK -15 1970320 500292274500 1.8 NA 1.8 NA 18.7 5/4/2011 NK -16 1940220 500292244700 2.5 NA 2.5 NA 20.4 5/4/2011 NK -17 1961650 500292270900 3 NA 3 NA 20.4 5/4/2011 NK -18 1931770 500292242100 2 NA 2 NA 17.0 5/6/2011 NK -19A 2010700 500292250701 1.8 NA 1.8 NA 15.3 5/6/2011 NK -20A 2050400 500292242901 2.1 NA 2.1 NA 13.6 5/9/2011 NK -21 1940860 500292248700 2 NA 2 NA 22.1 5/16/2011 NK -22A 2012280 500292240201 1.5 NA 1.5 NA 11.9 5/11/2011 NK -23 1940350 500292245500 3.6 NA 3.6 NA 20.4 5/10/2011 NK -25 1970880 500292276000 2.5 NA 2.5 NA 15.3 5/11/2011 NK -26 1940050 500292244000 2.9 NA 2.9 NA 17.0 5/11/2011 NK -27 1950210 500292254700 2.3 NA 2.3 NA 13.6 4/30/2011 NK -28 1960930 500292287800 Sealed Conductor NA Sealed Conductor NA NA NA NK -29 1961900 500292272400 1.7 NA 1.7 NA 10.2 4/30/2011 NK-38A 2042410 500292254001 3.1 NA 3.1 NA 13.6 5/8/2011 NK-41A 1971580 500292277801 9.1 NA 9.1 NA 54.0 5/9/2011 NK-42 1941080 500292249900 2 NA 2 NA 13.6 5/9/2011 NK-43 2010010 500292299800 1 NA 1 NA 5.1 5/9/2011 NK-61A 2060350 500292289301 14 NA 14 NA 110.5 5/15/2011 NK-62A 2030470 500292285201 1.3 NA 1.3 NA 13.6 5/4/2011 NK-65A 2050630 500292286901 1 NA 1 NA 8.5 5/6/2011 STATE PIPELINE COORDINATOR'S OFFICE ~ Department of Environmental Conservation - Department of Natural Resources _- Department of Fish and Game TONY KNO WLES, GOVERNOR 411 WEST 4t~ AVENUE. SUITE 2C ANCHORAGE. ALASKA 99501 PHONE: (907) 278-8594 (9071 278-8595 FAX: /907/272-0690 January, 12, 1995 Letter No' 94-08-DRT File No: 300.15.202 CERTIFIED MAIL RETURN' RECEIPT REQUESTED z 033 798 397 Mr. Steven D. Taylor BP Exploration ~Alaska) Inc. P. O Box ~9661'~ Anchorage. :~7. 99519-6612 Dear Mr. Tavior: Re: BP Exploration (Alaska) Inc. Inactive Drilling Waste Disposal Faciiits.' Closures - Numerous Inactive Sites The Alaska Department of Environmental Conser~,ation (ADEC) has received and completed its review of your August 9. 1993 letter, with enclosures, requesting approval for closure of BP Exploration (Alaska) Inc. Drilling Waste Disposal Facilities on the North Slope. These sites have been reviewed in accordance with the ADEC Interim Site Assessment Guidance for Inactive Drilling Waste Sites. June 1991. This correspondence describes our review procedures, puts forward the department's findings, and takes action on the requests. Currently, the second draft of Alaska's new Solid Waste Regulations, 18.AAC 60. are under review, and this second draft contains a chapter on Inactive Reserve Pit closures. The closure criteria in this proposed re=m.tlation parallels the closure criteria in the 1991 Guidance Document. Closure under the 1991 Guidance Document should constitute closure under the proposed Solid Waste Regulations if they are adopted as current drafted. The Review Procedure The qualitative risk screening procedure required in the above referenced document determines whether a site presents negligible levels of risk. or if it is a significant risk generator. A decision scheme is then employed to establish (1) whether or not there is a Mr. Steven D. Taylor January, 12, 1995 BPXA Inactive Drilling Waste Disposal Facilitv Closure Approval basis of concern, and (2) whether or not a waste site is liketv to present significant risk to human or environmental receptors. The first step in this screenin2 criteria is esrablishin~ a basis of concern: ., "If the waste site has released contaminants or there are mechanism for potential releases and there,are receptors nearby, then. there may be cause for concern, and the waste site should be studied further." and "If there is no release of contamination or no mechanisms for potential releases and there are no receptors nearbv, then there is not a basis for concern and the waste site should be considered closed." The criteria that are measured at a waste site to satisfy the above logical arguments are: Evidence of release of chemical contamination at the waste site in excess of Alaska Water Quality Standards for one or more target comr~ounds, or Mechanism for potential release, and Proximity of the waste site to biolo~_icai recemors. If either of the first two criteria and the last criteria are met. there is a basis for concern, and before proceeding with Step 2. a corrective action plan shall be prepared for the site which s.hall identify alternative ways to correct or mitigate the basis of concern, prevent its recurrence, and select a preferred approach. Corrective action alternatives shall be described at a conceptual level, and the selection of a preferred approach shall be based on balancing protectiveness with implementability and cost-effectiveness. The second step determines whether contamination at a waste site present a risk to receptors that is significant. If risk is found not to be significant, it is considered to be "negligible." The finding o,_rr%_ignificant risk is based on the likelihood of exposure and the likel~tho~od of adverse consequences of exposure: "For risk to be considered significant, the receptors must be vulnerable to exposure, and the consequences of exposure must be 'adverse' to human or animal health or the environment." and, conversely, "If exposure is untikelv or the consequences of exposure are not 'adverse,' then the risk is negligible. Mr. Steven D. Taylor January 12. 1995 BPXA Inactive Drilling Waste Disposal Facility Closure Approval If risk at a waste site is signficiant, then corrective action should be taken. The criteria that are evaluated at a waste site to satisfy the logical arguments above are exposure criteria and consequence criteria. Exposure Criteria: Receptor exposure is considered to be likely when: Contaminant release mechanisms are iudaed significant . or Containment migration is judged significant, or One or more contaminants are envirommenrally persistent. If exr~osure is found to be unlikelv, a findin~ of ne2ii_oible risk is made on the basis of absence of a likely exposure item and the action Nan is evaluated under the Impact/Benefit Evaluation step. The purpose of this step is to dete,,'Tnine whether the benefits of taking a corrective action would be greater than the impacts of taking such a corrective action. If any one of the exposure criteria are met. a finding is made that exposure is likely. Further screening then continues to evaluate Consequence Criteria. Consequence Criteria: Adverse consequences of exposure to contaminants from reserve pits are considered to be likely when: (a) The duration or frequency of exposure is sufficient to cause adverse health and environmental effects. This is evaluated bv reviewing human and wildlife use patterns at a given waste site, waste site accessibility, and ground and surface water uses. and either; (b) The quantity, or concentration of one or more contaminants exceeds pertinent federal or state water quality criteria or standards protecting health and/or the environment. Measured contaminant Concentrations in the water will be compared with health and environmental standards and criteria for each target contaminant, to identifs' exceedances. When only human populations are at risk, health criteria are used. When only populations at risk are nonhuman (e.g., fish. wildlife, vegetationl, environmental criteria and standards are used, or: (c) One or more contaminants exhibit high acute toxicity. The NIOSH toxicity rating system (NIOSH 1974) will be used to identify contaminants higNly toxic to mammals. This Mr. Steven D. Tavlor January 12. 1995 BPXA Inactive Drilling Waste Disposal Facility Closure Approval information wilt be used to determine whether a target compound exhibits acute hith toxicity. - - If the duration and frequency of exposure is insufficient to cause adverse effects, there is no need to evaluate the other two consequence criteria, and a findino_ of negligible_ ~ risk is made. If the duration and frequency term is sufficient, but neither of th~ other two consequence criteria are met. a finding of negligible risk is made. The action plan is then evaluated under the Impact/Benefit Evaluation step. tf the duration and freauencv of exposure is determined to be sufficient to cause adverse effects and either of the other two consequence criteria are satisfied, then a findin~ is made that adverse consequences are liketv, and the risk at a waste site is said to be si_onificant. If the screening indicates that risk is significant, then the responsible part5..' shall proceed with implementations of corrective actions. SITES CONSIDERED FOR CLOSURE Based upon the above referenced criteria from the June 1991 EYrER~4 SITE ASSESSMENT GUIDANCE FOR INACTIYE DRILLENG WASTE SITES. the following sites listed below have been reviewed for closure- ARCTIC FOOTHILLS SITES WEST S.~d,2 SITES Shale Wall Unit #1 b~-o~-~~ West Sak 4 Kemik Unit ~1 70-obo Kemik Unit #2 7'q' oB5 Kuparuk Unit 1 & lA 8-~-oi,87. o~ 7 Gubic Unit #1 Itkillik Unit No. 1 Finn Creek Unit 1 '~- ot PUT RIVER SITES Put River 13-10-14. 14-10-14 Put River 24-10-!4 6~.O3o COLVILLE DELTA SITES Nechelik Unit #1 SAG DELTA AREA Sag Delta Unit No. 1 t,a-o~,zf Sa~ Delta Unit No." '7~,-o~ 7 _ -, 10-11-16 I Sag Delta Unit No. 11 84-~t2-. OFFSHORE ISLANDS IN .ALASKAN WATERS Alaska Island #1 8/-tlq Niakuk 4. 5. 6 Challenge Island #1 Niakuk 1. lA. 2. 2A Niakuk 3 Mr. Steven D. Taylor January' 12. 1995 BPXA Inactive Drilling Waste Disposal Facility Closure Approval The decision to grant closure approval on these sites has been based (!5 on a review of the submitted inactive drillina waste site assessment documents listed below bv the ADEC-PCRO Solid Waste, Water Quality, and Contaminated Site Staff. and (25 site visits by PCRO staff during July of 1993 along-with the resultant recommended remedial actions by ADEC undertaken at a certain number of these sites. Title' Inactive Reserve Pit Program. Assessment and Closure Supporting Documents: BPXA Video-documeatation of Pit Closure/Site Restoration Comvarative Analysis of Soil & Water Samples Submitting Person' Dave Lowe. BP Exploration Alaska) Covered Facilities: Above Named Facilities Synopsis of Closure Procedure: Closed as is. No ~rther acnon is needed for the drilling waste facilities at these sites, except as noted below. CLOSURE APPROVALS The Department's decision uvon the reauest for closure application submitted bv BP Exploration (Alaska) Inc. is to approve for the below listed drilling waste facilities sites, effective January " 1_. :995. Upon review of the submitted sample results required under the 1991 Guidance. certain remote sites exhibited metal concentrations and hydrocarbons in the reserve put surface waters and downgradient waters in excess of the Alaska Drinking Water Standards and Alaska Water Quality Criteria (AWQCS. While there is a basis for concern for those sites where exceedances occurred, there is also nemble risk. and any corrective action warranted at these remote sites would not be required, realizing that the impact of the corrective action would be much greater than the benefits received. These sites~for the most part have revegetated, and any corrective action measures implemented would-impact the established plant species at these sites. These sites are Closed As Is. There are certain sites where corrective action is warranted, however, and Conditional Closure is granted, provided the corrective action stipulations described are completed to the department's satisfaction. Mr. Steven D. Tavlor Januarv 12. 1995 BPXA Inactive Drilling Waste Disposal Facilitw Closure Approval CLOSED AS IS Nechelik Unit gl ~ Sag Delta 11 ~ Alaska Island gl - Niakuk 4, 5, 6 ~ Challenge Island gl / Long Island #1 j' Niakuk 1, IA, 2, 2A / Niakuk 3 - Sag Delta 8 Sag Delta 3 & 4 . Sag Delta 5 ,- West Sak 4 Put River 13-10-14, 14-10-14 Put River 24-10-14 - Kemik Unit//2 l Gubic Unit #1 '~ CONDITIONALLY CLOSED These closure conditions were placed on the below-named sites following the site visit/closure package evaluation. These conditions have been met at each site and are now considered CLOSED. Sha~e Wall Unit #1 Remove unused drilling additives and pallets. Kemik Unit Stabilize anv exposed drilling waste in reserve pit Fertilize. plus seed and/or transplant with commercial or indigenous plant material Kuparuk Unit 1 & lA Stabilize any exposed drilling waste in reserve pit Surface preparation of site needed (scarifs.', add soil amendments, fertilize) Monitor site using aerial photography Mr. Steven D. Taylor January 12, 1995 BPXA Inactive Drilling Waste Disposal Facility Closure Approval Itkillik Unit No. 1 Stabilize any exposed drilling waste in reserve pit These conditions have been placed on the below-named sites following the site visit/closure package evaluation. Once these conditions have been met, these sites will be considered CLOSED' Finn Creek 1 Remove stockpiled debris from pad Fertilize. plus seed and/or transplant with commercial or indigenous plant material to enhance natural biodeeradation of residual hydrocarbon contamination in the soils and waters at the site Stabilize any exposed drilling waste in the reserve pit Sag Delta Unit No. 1 Sag Delta Unit No. 2 10-11-16 Cap existing reserve pits with available gravel and recontour pits to blend into surrounding terrain Terms and Conditions These closure approvals are subject to the following terms and conditions: FULL SITE CLOSU'R~E: The approval granted by this letter is for the inactive drilling xvaste sites only, as required under 18 AAC 60.500 (d). Closure for the pad as a whole must be coordinated between the owner/operator and the appropriate state (ADNR. ADF&G. AOGCC). or federal (BLM) agency. Additionally, should any contamination from historic spills be found on the pad outside the drilling waste site (reserve pit area), notification needs to be made to the ADEC/PCRO Contaminated Sites Section (271-4399). Mr. Steven D. Taylor, January' 1~.' 1995 BPXA Inactive Drilling Waste Disposal Facility Closure Approval NEW Eh'FORMATION: Should additional information concerning environmental conditions at the facility make further actions necessary, to protect human health or the environment, the Department rese?ves the right to require additional investigation, assessr~.',ent, monitoring, or retnediation at the facility. Mr. Steven D. Tavtor. January 11. 1995 BPXA Inactive Drilling Waste Disposal Faciiitv ClOsure Approval DL~FY TO RESPOND' Notwithstanding any other provisions or requirements of this closure approval, a person causing or permitting the discharge of oil or other hazardous substances is required bv law to immediately contain and clean-up the discharge. (AS 46.04.020' 46.09.020~. COMPLIANCE WITH APPLICABLE LAWS' If amendments to this closure approval are necessars' to meet the requirements of anv new laws or regulations, the facility owner/operator must submit an application for amendment to the Department at the above address. The facility owner/operator must adhere to all applicable state statutes and regulations as they max' be amended from time to time. If you have any questions, please do not hesitate to contact Tim Law at 271-4051 of this OrlylCe. Sincerely. - 4...__._.~m Chapple ADEC Regional Administrator Pipeline Corridor Region ALASKA OIL AND GAS CONSERVATION COMMISSION TONY KNOWLES, GOVERNOR $001 PORCUPINE DRIVE ANC! IORAGE. A I~%SKA 99501-3192 PI1ONE: (907)279-1435 TELECOPY: (907)276-7542 December 8, 1994 Land Department (MB12-1) Pete Zseleczky, Mgr BP Exploration (Alaska) Inc P O Box 196612 Anchorage, AK 99519-6612 Re: Location Clearance Inspections Four (4) North Slope Wells Dear Mr. Zseleczky: On October 1, 2,and 3, our Inspector John Spaulding accompanied your representative, Marian Sloan, on location inspections of several abandoned and suspended BPX North Slope wells; he recommended location clearance for three of those wells. .. Final Location Clearance is hereby approved for the following North Slope wells: PTD No. Well. Name & No. WH Abnd Date 76-028 Niakuk #lA 03/09/91 HRH 76-79 Niakuk #2A 03/13/91 not wit 81-119 Alaska Island #1 08/14-25/88 not wit Chairman ~ ~ bew/a 1: 2bpnkwls STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL CO PLE'I'ION OR RECOUP LETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL [] GAS [] SUSI=ENDED I"1 ABANDONED r'tx SERVICE [] 2. Name of Operator 7. Permit Number BP Exploration (Alaska) Inc. 76-79 3. Address 3. APl Number P. O. Box 196612, Anchorage, Alaska 99519-6612 50- 029-20180-01 4. Location of well at surface ~). Unit or Lease Name 1726' NSL, 1130' WEL, SEC. 26, T12N, R15E ~ . At Top Producing Interval i ]~O~"AT~O~ 10. Well Number N/A i ~ NK-2A 11. Field and Pool At Total Depth Wildcat 2457' NSL, 362' WEL, SEC. 23, T12N, R15E 5. Elevation in feet (indicate KB, DF, etc.) ~6. Lease Designation and Serial No. KBE = 27.98' AMSL I ADL 34625 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 115. Water Depth, if offshore 116. No. of Completions 1/3/77 3/17/77 3/13/91I N/A feet USE I Zero 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVDI 19. Directional Survey ~20. Depth where SSSV set ~1. Thickness of Permafrost 12564' MD/10150' TVD Surface YES [] NO []! None feet MD! 1800' (Approx.) 22. Type Electric or Other Logs Run DIL/BHCS, Continuous Dipmeter, FDC/CNL/GR/CAL, CBL/VDL/GR/CCL, Mud log 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE VVT. PER FT. GRADE TOP BO'i-rOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 20" 94~ H-40 Surface 78' 26" 80 cu 13-3/8" 72# N-80 Surface 2714' 18-1/2" 3906 cu 9-5/8" 47# N-80/S0O-95 2108' 10997' 12-1/4" 3050 cu ft 9-5/8" 47# N-80 Surface 2119' 12-1/4" Tieback 7" 29# N-80 8297' 12564' 8-1/2" 2156 cu 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MDI PACKER SET (MDI None None None 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED see attached diagram 27. PRODUCTION TEST Date First Production IMethod of Operation (Flowing, gas lift, etc.) Not on production I N/A Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF ~ATER-BBL CHOKESIZE IGAS-OIL RATIO I TEST PERIOD Flow Tubing Casing Pressure ;ALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips, and presence o! oil, gas or water. Submit core chips. k\~sV,a ~)6 & GsS Cons. C, omm'tss'ton Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 29. 30. GEOLOGIC MARKERS FORMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Subsea Kuparuk 11114' 9103' Kingak 11300' 9216' 31. LIST OF ATTACHMENTS 32. I hereby certify/~that the foregoing is true and correct to the best of my knowledge /I Signed . Title Drillino Engineer Suoervisor Date f( ~ c~ ~ INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and Icg on all types of lands and leases in Alaska. Item 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. R F. C [IV E ¢ Item 28: If no cores taken, indicate "none". Form 10-407 ARchor'a. ~. Niakuk #2A Abandonment 1. Notified Harold Hawkin of AOGCC prior to commencing operations. 2. Removed ice and fill in cellar to allow access to all wellhead equipment. 3. Removed 13-5/8" blind flange. Run in hole with coil tubing and circulated to hard TD at 7500' 4. RIH with motor and underreamer, zeroed at base flange. Drilled to 7760' hard fill. Obtained verbal approval from AOGCC on 3/11/91 to lay cement plug at this point. POOH w. coil tubing, laid down underreamer. 5. RIH with 9-5/8" explosive cutter. Cut 9-5/8" casing at 54' below ground level. Pulled 9-5/8" casing sub with crane. Laid down and measured 56.5'. 6. RIH with coil tubing nozzle. Pressure tested well to 3000 psi, 20 min. Test good, chart on file in the Drilling department. Laid cement from TD to 7570'. 7. Lay 10.4 ppg mud from 7570' to 225' and permafrost grade cement from 225' to surface, displacing diesel from wellbore. Dressed off top of cement at surface. Allowed cement to set and tagged cement top at 19.5' below base flange. 7. Excavated wellhead and cut all casing stubs to 7.0' below base flange (2 to 3 feet below mudline). Obtained photographs of well after cut for H. Hawkin of the AOGCC. Rigged down equipment on 3/13/91, moved off location, police area. Site abandonment currently under operation. RECEIVED NOV -2 1994 A, iaska OlJ & Gas Cons. Commission Anchor~ .~ CEMENT NI AKUK =2A ACTUAL POST SUSPENSION WELLDORE DIAGRAM ARCTIC PAK Base Flange Elev. = 5.09' AMSL KB Elev. = 27.98' AMSL MD (BKB) Cut casing stubs (2 ft* below I~I/L, 10.0' below B.F.) CEMENT PLUG z12.5-248 FT CUT 9-5/8" CASING STUB ?9.5 FT 20"CONDUCTOR 9 5/8" 47¢/FT N-80 BTC CASING TIE-BACK -78 FT 9 5/8" CASING HANGER W/ PBR 2109 FT 3/8" 72¢/FT N-80 BTC KOP (DIR:NI.O"E MAX. ANGLE:46') 2714 FT 2800 FT I0.4 PPG MUD RECEIVED ,%.'EP $ 0 i994 A~,ska Oil & Gas Cons. Commission Anchorz.:,e CEMENT PLUG BARITE FILL 9 5/8" EZ DRILL PACKER 7570-7760 FT 776O-82O4 FT 8204 FT 7" LINER TOP 8297 FT 10.4 PPG MUD 9-5/8" 47='/FT N-80 BTC (WINDOW MILLED ON BOTTOM SIDE OF 9-5/8" CASING IN NIAKUK ¢2 TO SIDETRACK NIAKUK =~2A) PBTD CEMENT PLUG HOWCO 7"EZ DRILL PACKER 7" 29¢/FT N-80 BUTT LINER PERFORATION DEPTH: 12222'-12294' 8830 FT RECEIVE NOV - ? 19Ltq Aiaska Oil & Gas Cons. Cornrnlssion Anchor~ I 1894 FT 11894-12170FT 12170-12177 FT 12564 FT PGS 3-20-91 BP EXPLORATION TO' From: David W. Johnston Chairman Alaska Oil & Gas Commission Steve Horton, Drlg Mgr Shared Services Drilling ARCO Alaska, Inc.--~'~ ~--~',,,~ --N~ ^s~'r I rILE Subject: Suspended wells Compliance with regulations In response to your letter dated August 15, 1994 regarding suspended wells attached are lists detailing well status and criteria for maintaining these wells in a suspended status. Plans for well inspections are in place for October 1 through October 3, 1994 as discussed with Blair Wondzell and John Spaulding. Updated reporting has been filed with the commission as listed. Yours Sincerely, Steve Horton Drilling Manager CCe Bill Bredar Patrick Collins Jim Farnsworth Mike Miller Bruce Policky Scott Sigurdson Marian Sloan RECEIVED OCT 1 4 1994 Alaska 0il & Gas Cons. Commission Anchor~a Suspended Wells, Request to retain suspension status The following wells are listed as suspended by the AOGCC under 20 AAC 25.110. These wells are requested to remain suspended for the reason(s) as indicated. Site inspections should be conducted as soon as possible. MPA-01; 029-20376-00 79-.~04 Potential recompletion in the Kuparuk C and/or B sand as a water injector. Decision hinges on 1994/95 development drilling results (E-13) in this area. MPB-02; 029-20662-00 81-/¢/142 This well is scheduled for initial completion in the Schrader Bluff late this year or early next year. MPA-03; 029-20891-00 83-.,¢001 Future utility as a Schrader Bluff producer with producing utility when surface infrastructure is installed on A pad. MPN-01 B; 029-21053-02 84-0O 13 N-01 B is a usable well in the Schrader Bluff, with producing utility when surface infrastructure is installed on N pad. The well should be retained in a suspended status until that time. MPC-16; 029-21364-00 85-0110 C-16 has recompletion potential in the Kuparuk "C" sand and/or the Schrader Bluff horizons. Although additional evaluation must be performed to quantify reserves and production potential, C-16 is believed to be a viable workover and/or sidetrack candidate. NWM#1; 029-22231-00 91-0145 Northwest Milne #1 should remain suspended until the Northwest Milne Point development is better defined. The wellbore is strategically located on a gravel island and may. possess utility in either production or injection operations. DNR recently'certified this well as capable of production. No Point #1;029-22450-00 94-0027 No Point #1 will be utilized in the upcoming F- Pad development. Expectations are to complete the Kuparuk "A" zone and commence production 4Q95. Niakuk #4, 029-21217-00 84-0200 Niakuk #4 is requested to remain suspended until the viability of the well for monitoring is defined. Niakuk #5, 029-21290-00 85-0027 Niakuk #5 should remain suspended for observation purposes at this time. Sag Delta #33-12-16, 029-20176-00 75-0058 Area being drained by 1994 Alapah well NK-26 (HAW). Potential use as a monitor well for this new reservoir Would have to truck oil across winter ice road if resume production Produced 186 MBO in 1985 2 month production' test. Sag Delta #5, 029-20527-00 80-0129 Area being drained by L5-26 (high gas well), L5-28, and L5-36 from south to west. Well tests indicated fairly tight, but productive rock; perhaps inadequate stimulation? Costs prohibitive for eventual tie-in to L5 (? via Heald Point). Potential for gas cap monitor well Sag Delta 31-11-16, 029-20011-00 69-0014 Area being drained by L4-36, 80 Acre offset to NW. Potential for service well (water injection?) Well is capable of production, but most Lisburne in water leg and costs likely prohibitive for tie-in to L4. Sag Delta #2A, 029-20234-01 77-0069 South of Sag Delta #1, in water leg of Alapah oil accumulation in NK-26 well. Remote potential for pressure monitoring of Alapah offtake and the effect on the Alapah aquifer; though, costs would likely be prohibitive. Sag Delta #8, 029-20519-00 80-0121 Z-32A, 029-21924-01 93-0113 S-10A, 029-20765-01 91-0123 Sag Delta #8 should remain suspended until the development plan for the area is better defined. This well may possess utility for production or as an observation well. Z-32 was shut in due to high water production in 1992. In 1993 it was sidetracked to a new location. The oil column at the new location was less than prognosed and was not considered economic and the well was suspended. There is oil in the area that can be reached as a new sidetrack from this well. A specific location has not yet been identified, but we wish to retain this wellbore for a future sidetrack. S-10 was sidetracked in 1992. Drilling difficulties were encountered while drilling through a fault in the Kingiak and the well was suspended. There is oil in the area that can be reached as a new sidetrack from this well. A specific location has not yet been identified, but we wish to retain this wellbore for a future sidetrack. The West Sak formation, a non unitized formation in the PBU license area, is reachable from this wellbore. Work in ongoing on a facility sharing agreement. In the case that a satisfactory agreement is reached, this wellbore could be used to access oil in this formation. Y-22A, 029-21558-01 88-0115 Y-22 was sidetracked in 1988. The sidetrack was suspended due to drilling difficulties. There is oil in the region that can be reached as a new sidetrack from this well. A location has not been worked on but we wish to retain this wellbore for a future sidetrack. U-01, 029-22244-00 92-0011 There is oil in the area that can be reached as a new sidetrack from this well. A specific location has not yet been identified, but we wish to retain this wellbore for a future sidetrack. PR 33-12-13, 029-20047-00 69-0104 The well penetrates The West Sak and Ugnu formations in the aquifer. Work in ongoing on a facility sharing agreement with subsequent appraisal of the formations. This well could be used to test the aquifer properties. These wells are listed as suspended, action items are detailed. Ak Island ¢1,289-20018-00 81-0119 Alaska Island ¢1 was abandoned in 1988. The completion notice has been refiled with AOGCC on 9/15/94. The site is ready for inspection (priority 1 ). Niakuk ¢1 A, 029-20156-01 76-0028 Niakuk ¢1A was abandoned in 1991. A sundry application requesting status change was filed with AOGCC 9/20/94. A completion notice will follow when the sundry application is approved. The site is ready for inspection (priority 1). Niakuk ¢2A, 029-20180-01 76-0079 Niakuk ¢2A was abandoned in 1991. A sundry application requesting status change was filed with AOGCC 9/20/94. A completion notice will follow when the sundry application is approved. The site is ready for inspection (priority 1). PBU H-01, 029-20099-00 71-0015 The well was drilled in 1971 and hit a down thrown fault block with only 20ft of oil bearing Ivishak. This was not economic at the time. It was left suspended without tubing. Recent success in fraccing the Sag formation indicated that it might be an economic well. A rig workover was completed in April 1994 and the well was put on production 9/94. It is not necessary to inspect this site. Kemik Unit ¢1,223-20006-00 70-0060 Kemik Unit ¢1 is scheduled to be abandoned in the near future. Abandonment planning is now in progress. Site insPection will not be necessary at this time most likely should be scheduled for Spring of 1995. P2-59, 029-22096-00 90-0140 Arco Alaska Inc. is the operator of this well, they will be addressing the question of suspension. Sag Delta ¢3, 029-20233-00 79-0080 Well plugged and abandoned March, 1991. Well completion notice will be refiled with the Commission. Sag Delta #4, 029-20245-00 77-0015 Well plugged and abandoned March, 1991. Well completion notice will be refiled with the Commission. The following wells are not under BP Exploration ownership. A letter requesting the owners to respond regarding their wishes for these wells was sent on 9/30/94. MP 03-10-12, 029-20483-00 80-O066 MP 33-11-12, 029-20504-00 80-0092 CHEV 18-11-12, 029-20511-00 80-0108 Term C 03-11-12, 029-20356-00 78-0102 MP 22-31-11-13, 029-20545-00 81-0010 MP 43-31-11-13, 029-20536-00 80-0139 MP 30-11-13, 029-20546-00 80-0152 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: David~ DATE: October 2, 1994 Chairrr~n TtlRU: Blair Wondzell, .ar~~ FlEE :NO: 2991jbbd.doc P. !. Supervisor .~o/~..~ John Spaulding,Q~, Petroleum Insp. ~)~,l~ A'~ FROM: SUBJECT: Suspended Wells Inspection North Slope, Alaska ,October 1,2&3, '1994: I accompanied Marian Sloan BPX representative on an inspection tour of BPX suspended wells at various North Slope locations. Travel was by pickup and helicopter. Marian Sloan Informed me that BPX is drafting a program with reasons for leaving wells listed below as suspended, this program will be available to the AOGCC in the very near future Oct. 1,1994 Y-22A / PBU / PTD 88-1.15; well head on configuration, no pressure on tubing or annulus, area very clean, well is located on a producing drillsite. S-10A / PBU / PTD 91-123; wellhead on configuration, no pressure on tubing or annulus, area clean, well is located on a producing drillsite. U-01 / PBU / PTD92-11; wellhead on configuration, no pressure on tubing or annulus, area clean, well is located on a producing drillsite. Z-32A / PBU / PTD 93-113; wellhead on configuration, no pressure on tubing, 750 psi on inner annulus, 0 pressure on outer annulus, area clean, well is located on producing drillsite. Chevron 18-11-12 / PTD 80-108; wellhead on configuration, no pressure on tubing or annulus, area clean. MP 22-31-11-13 / PTD 81-10; wellhead on configuration, no pressure on tubing or annulus, area clean, reserve pit is still open. MP 32-30-11-13 / PTD 80-152; wellhead on configuration, no pressure on tubing or annulus, area clean, reserve pit is still open. Oct. 2, 1994: A-01 / MPU / PTD 79-40; wellhead is removed with casing hanger still on, area clean, well is located on a active drillsite. A-03 / MPU / PTD 83-01; wellhead on configuration, no pressure on tubing or annulus, area clean, well is located on a active drillsite. B-02 / MPU / PTD 81-142; wellhead on configuration, no pressure on tubing or annulus, area clean, well is located on a producing drillsite, C-16 / MPU / PTD 85-116; wellhead on configuration, no pressure on tubing or annulus, area clean, well is located on a producing drillsite. N-01B / MPU / PTD 84-13; wellhead on configuration, no pressure on tubing or annulus, area clean with timbers covering the cellar area and well guard around the wellhead. No Point #1 / MPU / PTD 94-27; wellhead on configuration, area clean, unable to land helicopter to check wellhead for pressures, No Point #1 is scheduled to become part of the F- pad construction at MPU. NW Milne #1 / MPU / PTD 91-145; wellhead on configuration, area clean, island is suffering from severe-erosion on the North side. Oct. 3, .!994: Sag Delta 31-11-16 / PTD 69-14; wellhead on configuration, area clean, has wooden location marker, no pressure on tubing or annulus. Sag Delta #3 / PTD 76-80; wellhead on configuration, area clean no pressure on tubing or annulus. Sag Delta #4 / PTD 77-15; wellhead on configuration, area clean, no pressures on tubing or annulus. .Sag Delta #2A/ PTD 77-69; wellhead on configuration, no pressures on tubing or annulus, timbers and cellar box material, reserve pit open. Sa,q Delta #5 / PTD 80-129; no wellhead; bell shaped affair was covering the supposed well surface location, area clean. Sa.q Delta #8 / PTD 80-121; wellhead on configuration, timbers and well guard, island is eroding. Alaska Island #1 / PTD 81-119;. unable to land, area appeared clean from the air, marker post visible on South side of island. Niakuk ~ / PTD 84-200;. wellhead on configuration, concrete river weights, cellars open, island eroding. Niakuk #5 / PTD 85-27; wellhead on configuration, concrete river weights, cellars open, island eroding. Location Clearances; Niakuk #lA / PTD 76-28; area is clean, no visible marker post, island is eroding as planned. (~iakuk #2A / PTD 76-79;...area -i.s-clean;-no-visible-marker-post; ..island.-is-eroding as planned. I recommend that the AOGCC consider Niakuk lA & 2A for final abandonment and location clearance. , Summary.: I inspected locations of 28 BPX suspended wells. I also inspected 2 wells for final abandonment and location clearances. STATE OF ALASKA ALA3KA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon x Suspend __ Operation Shutdown __ Re-enter suspended well__ Alter casing __ Repair well __ Plugging x Time extension __ Stimulate __ Change approved program __ Pull tubing __ Variance __ Perforate __ Other x 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P. O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 1726' NSL, 1130' WEL, SEC. 26, T12N, R15E At top of productive interval 2289' NSL, 479' WEL, SEC. 26, T12N, R15E At effective depth At total depth 2457' NSL, 362' WEL, SEC. 23, T12N, R15E 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical __ Reclassify well 5. Type of Well: Development Exploratory x Stratigraphic Service 6. Datum elevation (DF or KB) kbe = 27.98 AMSL feet 7. Unit or Property name Prudhoe Bay Unit 8. Well number Niakuk tt2A (23-12-15) 9. Permit number 76-79 10. APl number 50- 029-20180-01 11. Field/Pool Wildcat (Exploration) 12564 feet 10150 feet Plugs (measured) see attached diagram feet feet Junk (measured) Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: measured Length Size 20" 13-3/8" 9 -5/8" 7~ 12222~12294'(squeezed) true vertical Tubing (size, grade, and measured depth) None Packers and SSSV (type and measured depth) None Cemented Measured depth True vertical depth 80 cu ft 78' 3906 cu fl 2714' 3050 cu fl 10997' 2156 cu fl 8297,- 12564' RECEIVED Si!P 30 1994 ,i, ,,,,~, ~,,, ,.~, & 6as Cons. Commission Anch0ra0~ 13. Attachments Description summary of proposal x Detailed operations program __ BOP sketch 14. Estimated date for commencing operation N/A 16. If proposal was verbally approved Name of approver Date approved 15. Status of well classification as: Oil Gas Suspended x Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed '"~?~(_.~:UrZ~ ~.(.~ Title Drilling Engineer Supervisor FOR COMMISSION USE ONLY Date Conditions of approval: Notify Commission so representative may witness Plug integrity ~ BOP Test~ Location clearance ~ Mechanical Integrity Test~ Subsequent form required 10- Original Signed By Approved by order of the Commission David W. Johnston IApproval No. ~?.... ~.? ~ Commissioner Date ,,~/-~.?/'~) ?' Form 10-403 Rev 06/15/88 Approved Copy Returned SUBMIT I1~ TRII~LICATE Reclassification of Well Niakuk #2A To Abandoned Status Please reclassify well Niakuk #2A as abandoned. Abandonment requirements were met in March, 1991. Attached are the procedures that were followed at that time and a wellbore diagram detailing the well condition. RECEIVED Niakuk 2A Re-suspension Procedure . . . . 0 Notified Harold Hawkin of AOGCC prior to commencing operations. Removed ice and fill in cellar to allow access to all wellhead equipment. Removed 13-5/8" blind flange. Run in hole with coiled tubing and circulated to hard TD at 7500'. RIH w/motor and underreamer, zeroed at base flange. Drilled to 7760' hard fill. Obtained verbal approval from AOGCC on 3/11/91 to lay cement plug at this point. POOH w/coiled tubing, laid down underreamer. RIH w/9-5/8" explosive cutter. Cut 9-5/8" casing at 54' below ground level. Pulled 9-5/8" casing stub with crane. Laid down and measured 56.5'. Run in hole w/Coiled tubing nozzel. Presure tested well to 3000 psi, 20 min. Test good, chart on file in the Drilling department. Laid cement from TD to 7570'. · Lay 10.4 ppg mud from 7570' to 225' and permafrost grade cement from 225' to surface, displacing diesel from wellbore. Dressed off top of cement at surface. Allowed cement to set and tagged cement top at 19.5' below base flange. Excavated wellhead and cut all casing stubs to 10.0 feet below base flange (2 to 3 feet below mudline). Obtained photographs of well after cut for H. Hawkin of the AOGCC. Rigged down equipment on 3/13/91, moved off location, police area. Site abandonment currently under operation. PGS 3/20/91 RECEIVED A.i~ska 0it & 6as Cor~s. Commission CEMENT NI AKUK =2A ACTIJAI POST SUSPENSION WELLBORE DIAGRAM lARCTIC PAK Base Flange Elev. = 5.09' AMSL KB Elev. = 27.98' AMSL MD (BKB) Cut casing stubs (2 ft+ below M/L, I0.0' below B.F.) CEMENT PLUG 42.5-248 FT CUT 9-5/8" CASING STUB 79.5 FT 20"CONDUCTOR 9 5/8"47~/FT N-80 BTC CASING TIE-BACK 78 FT 5/8" CASING HANGER W/ PBR 2109 FT 13 3/8" 72=/FT N-80 BTC KOP (DIR: N i.O'E MAX. ANGLE: 46') 2714 FT 2800 FT 10.4 PPG MUD RECEIVED SEP $ 0 199q Ai~,ska Oil & Gas Cons. Corrimi$sJort Anchom?, CEMENT PLUG 7570-7760 FT BARITE FILL 9 5/8" EZ DRILL PACKER 7760-8204 FT 8204 FT 7" LINER TOP 8297 FT 10.4 PPG MUD 9-5/8" 47¢/FT N-80 BTC (WINDOW MILLED ON BOTTOM SIDE OF 9-5/8" CASING IN NIAKUK #2 TO SIDETRACK NIAKUK ¢2A) 8830 FT PBTD CEMENT PLUG HOWCO 7"EZ DRILL PACKER 7" 29~/FT N-80 BUTT LINER PERFORATION DEPTH: 12222' - 12294' 11894FT Ii894-12170 FT 12170-12177 FT 12564 FT PGS 3-20-91 ALASKA OIL AND GAS CONSERVATION COMMISSION WALTER J. HICKEL, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 TELECOPY: (907) 276-7542 August 15, 1994 Steve Horton, Drlg Mgr BP Exploration (Alaska) Inc P O Box 196612 (MB12-1) Anchorage, AK 99519-6612 Re: Suspended Wells Compliance with regulations Dear Mr. Horton: BP Exploration and the predecessor Sohio companies have several suspended wells as shown on the attached lists: BP SUSPENDED WELLS PRIOR TO 1980 and BP SUSPENDED WELLS SINCE 1980. The applicable regulation is as follows: 20 AAC 25.110 SUSPENDED WELLS (a) Upon application by the operator under 20 AAC 25.105(e), the commission will, in its discretion, approve the suspension of a well if the well (1) encounters hydrocarbons of sufficient quality and quantity to indicate the well is capable of producing in paying quantities as reasonably demonstrated by well tests or interpretive formation evaluation data; or (2) is reasonably demonstrated to have future value as a service well. For each well on the attached lists of suspended wells, please provide data showing that the well meets the criteria of (1) or (2) above, or advise as to your plans to abandon the well. Wells that meet the criteria of (a) above that you wish to maintain as suspended, as r.~equire~ 20 AAC 25.110(e), must have well site inspections Mis ye~r-~'rl ~t0 snow covering the locations. David W.(Johnston X ' Chamrman ..... ....~~~ Attachments c: Blair Wondzell hew/llbpsusp :/15/94 BP SUSPENDED WELLS SINCE 1980 PAGE 1 AUGUST 1994 P~RMIT 79-0040-0 80-0066-0 80-0092-0 80-0108-0 80-0121-0 80-0129-0 80-0139-0 80-0152-0 81-0010-0 81-0119-0 81-0142-0 83-0001-0 84-0013-0 84-0200-0 85-0027-0 85-0110-0 88-0115-0 90-0140-0 91-0123-0 91-0145-0 92-0011-0 93-0113-0 94-0027-0 API NUMBER 029-20376-00 029-20483-00 029-20504-00 029-20511-00 029-20519-00 029-20527-00 029-20536-00 029-20546-00 029-20545-00 089-20018-00 029-20662-00 029-20891-00 029-21053-02 029-21217-00 029-21290-00 029-21364-00 029-21558-01 029-22096-00 029-20765-01 029-22231-00 029-22244-00 029-21924-01 029-22450-00 WELL WELL WELL NAME CLASS STATUS MILNE POINT UNIT A-01 EXP SUSP PRTJDHOE BaY UNIT 3-10-12 DEV SUSP PBU MP 11-33-11-12 1 DEV SUSP PRUDHOE BaY UNIT TR 18-11-12 DEV SUSP SAG DELTA 8 EXP SUSP SAG DELTA 5 EXP SUSP PRUDHOE BaY UNIT 31-11-13 DEV SUSP PBU MP 32-30-11-13 1 DEV SUSP PBU MP 22-31-11-13 2 DEV SUSP ALASKA ISLAND I EXP SUSP MILNE POINT LINIT B-02 DEV SUSP MILNE POINT UNIT a-03 DEV SUSP MILNE POINT UNIT N-01B DEV SUSP NIAKUK 4 EXP SUSP NIAKUK 5 EXP SUSP MILNE POINT LrNIT C-16 DEV SUSP PRUDHOE BaY UNIT Y-22A DEV SUSP PT MCINTYRE P2-59 EXP SUSP PRUDHOE BaY UNIT S-10A DEV SUSP NORTI-IWEST MILNE 1 EXP SUSP PRUDHOE BaY UNIT U-01 DEV SUSP PRUDHOE BaY UNIT Z-32A DEV SUSP NO POINT I DEV SUSP STATUS DATE 4115180 10/11/80 4/29/81 12/24/80 4/15/81 4/13/81 2/20/81 1/i8/81 2/14/81 6/08/82 5/27/82 12/10/83 4/27/84 2/17/85 4/i8/85 10/27/93 10/29/88 12/22/90 11/06/91 3/30/92 3/16/92 8/31/93 4/08/94 SECT 23 33 33 O7 27 36 0S 3O 3O 11 19 23 3O 25 25 10 33 14 35 25 18 19 O6 TWP 13N llN llN lin 12N 12N iON llN llN iON 13N 13N 13N 12N 12N 13N llN 12N 12N 14N liN lin 13N 010E 012E 012E 012E 016E 01SE 013E 013E 013E 022E 011E 010E 010E 015E 015E 010E 013E 014E 012E 009E 013E 012E 010E MER U U U U U U U U LI U U U U U U U U U U U U U U /15/94 BP SUSPENDED WELLS PRIOR TO 1980 AUGUST 1994 PERMIT 69-0014-0 69-0104-0 70-0060-0 71-0015-0 75-0058-0 76-0028-0 76-0079-0 76-0080-0 77-0015-0 77-0069-0 78-0102-0 API NUMBER 029-20011-00 029-20047-00 223-20006-00 029-20099-00 029-20176-00 029-20156-01 029-20180-01 029-20233-00 029-20245-00 029-20234-01 029-20356-00 WELL WELL WELL NAME CLASS STATUS SAG DELTA 31-11-16 EXP SUSP PRUDHOE BaY UNIT 33-12-13 DEV SUSP KEMIK UNIT i DEV SUSP PRUDHOE BaY UNIT H-01 DEV SUSP SAG DELTA 33-12-16 EXP SUSP NIAKUK 1-m EXP SUSP mIaKUK 2-a EXP SUSP SAG DELTA 3 EXP SUSP SAG DELTA 34633 4 EXP SUSP SAG DELTA 28337 2-a EXP SUSP PRUDHOE BaY UNIT TERM C DEY SUSP STATUS DATE 4/28/69 12/20/69 6/17/72 6/22/71 4/28/76 4/30/76 3/30/77 3/23/77 3/22/78 12/27/77 4/25/79 SECT 31 33 17 21 04 26 26 35 35 10 O3 TWP llN 12N 01N 11N lin 12N 12N 12N 12N llN lin RNG 016E 013E 020E 013E 016E 015E 015E 016E 016E 016E 012E MER U U U U U U U U U U U STATE OF ALASKA A,.,-,6KA OIL AND GAS CONSERVATION COMMIS,~,,. ,N REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown Stimulate Plugging X Perforate Pull tubing Alter casing Repair well Other 2. Name of Operator BP Exploration 3. Address P. O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 1726'NSL, 1130' WEL, SEC. 26, T12N, R15E, UM At top of productive interval 2289' NSL, 479' WEL, SEC. 26, T12N, R15E, UM At effective depth At total depth 2457' NSL, 362' WEL, SEC. 23, T12N, R15E, UM 12. Present well condition summary Total depth: Effective depth: 5. Type of Well: Development Exploratory Stratigraphic Service 6. Datum elevation (DF or KB) KBE =, 27.98'AMSL feet 7. Unit or Property name Prudhoe Bay Unit 8. Well number Niakuk #2A (23-12-15) 9. Permit number/approval number 76-79/91-002 10. APl number 50- 029-20180-01 11. Field/Pool Wildcat (Exploration) measured true vertical measured true vertical 12564' feet Plugs (measured) 10150' feet BKB 8204' feet Junk (measured) 7106' feet BKB Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Length Size Cemented Measured depth True vertical depth measured 20" 80 cuft 78'MD 13-3/8" 3906 cu ft 2714'MD 9-5/8" 3050 cu ft 10997'MD (Niakuk #2) 7" 2156 cu ft 8297'- 12564'MD 12222'- 12294'. Reason for resuspension: To complete plug & abandonment operations for future reclassification to same. true vertical Tubing (size, grade, and measured depth) Kicked off at 8830'-8868'. Packers and SSSV (type and measured depth) None None Note: This well was drilled from the same surface location as Niakuk #2 (Abandoned). 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure Oil& Gas Cons. ''..Anchorage, 14. Prior to well operation Subsequent to operation Reoresentative Daily Averane Producticn or Iniection Data - OiFBbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run Daily Report of Well Operations Oil Gas. Suspended x Service I 17..~.t-here, by certify that the foregoing,is true and correct to the best of my knowledge. I~d;~'~ /~~-~~ Title Completion En~ineerin~Supervisor Form 10-404 Rev 06/15/88// SUBMIT IN DUPLICATE Niakuk 2A Re-suspension Procedure , m 1 , 1 Notified Harold Hawkin of AOGCC prior to commencing operations. Removed ice and fill in cellar to allow access to all wellhead equipment. Removed 13-5/8" blind flange. Run in hole with coiled tubing and circulated to hard TD at 7500'. RIH w/motor and underreamer, zeroed at base flange. Drilled to 7760' hard fill. Obtained verbal approval from AOGCC on 3/11/91 to lay cement plug at this point. POOH w/coiled tubing, laid down underreamer. RIH w/9-5/8" explosive cutter. Cut 9-5/8" casing at 54' below ground level. Pulled 9-5/8" casing stub with crane. Laid down and measured 56.5'. Run in hole w/Coiled tubing nozzel. Presure tested well to 3000 psi, 20 min. Test good, chart on file in the Drilling department. Laid cement from TD to 7570'. Lay 10.4 ppg mud from 7570' to 225' and permafrost grade cement from 225' to surface, displacing diesel from wellbore. Dressed off top of cement at surface. Allowed cement to set and tagged cement top at 19.5' below base flange. Excavated wellhead and cut all casing stubs to 10.0 feet below base flange (2 to 3 feet below mudline). Obtained photographs of well after cut for H. Hawkin of the AOGCC. Rigged down equipment on 3/13/91, moved off location, police area. Site abandonment currently under operation. PGS 3/20/91 ~i CEMENT NI AKUK #2A ACTUAL POST SUSPENSION WFLLBORE DIAGRAM ARCTIC PAK Base Flange Elev, = 5.09' AMSL KB Elev. = 27.98' AMSL ~D (BKB) Cut casing stubs (2 ft+ below M/L, I0.0' below B,F.) CEMENT PLUG 42.5-248 FT 79.5 FT 78 FT CUT 9-5/8" CASING STUB 20"CONDUCTOR 9 5/8"47#/FT N-80 BTC CASING TIE-BACK 9 5/8"CASING HANGER W/ PBR 2109 FT 13 3/8" 72#/FT N-80 BTC KOP (DIR: NI.O°E MAX, ANGLE: 46°) 2714 FT 2800 FT 10.4 PPG MUD CEMENT PLUG 7570-7760 FT BARITE FILL 9 5/8" EZ DRILL PACKER 7760-8204 FT 8204 FT 7"LINER TOP 8297 FT 10.4 PPG MUD 9-5/8" 47#/FT N-80 BTC (WINDOW MILLED ON BOTTOM SIDE OF 9-5/8" CASING IN NIAKUK #2 TO SIDETRACK NIAKUK #2A) 8830 FT PBTD CEMENT PLUG HOWCO 7"EZ DRILL PACKER 7" 2g#/FT N-80 BUTT LINER PERFORATION DEPTH: 12222'-12294' I 1894 FT 11894-12170 FT 12170-12177 FT 12564 FT PGS 3-20-91 BP EXPLORATION Tuesday, January 8, 1991 BP Exploration (Alaska) Inc. 900 East Benson Boulevard RO. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 Lonnie Smith Alaska Oil & Gas Conservation Commission 3001 Porcupine Dr. Anchorage, Alaska 99501 Dear Sir: Please find enclosed an Application for Sundry Approval to re-suspend Niakuk well 2A. Enclosed you will also find pertinent maps of the location, a wellbore diagram, a procedure outline for the operation, and a letter from the DNR confirming our intentions to suspend the well. Suspension operations are scheduled for the first quarter of 1991. Niakuk 2A currently has a 276 ft cement plug on top of a 7" bridge plug in a fully cemented and pedorated liner. The perforated interval is 44 feet below the 7" bridge plug. A 9-5/8" bridge plug is set 93 feet above the 7" liner top. 10.4 ppg mud fills the wellbore except for a 2000' diesel cap. The remainder of the suspension work is detailed in the attached Outline Proce- dure. Left as detailed, Niakuk 2A can be re-classified as plugged and abandon if and when it is deemed necessary. If you have any questions pertaining to this application, please contact myself at 564-4026 or Phil G. Smith at 564-5475. PGS:pgs cc: R.H. Reiley A. S. Macfarlan~ Niakuk 2A Well File Sincerely, Burt Littlefield Completions/Workover Supervisor RECEIVED JAN 08 1991 ' --' STATE OF ALASKA AL A OIL AND GAS CONSERVATION COMMIS~. .~ APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon ~ Suspend X Alter casing ~ Repair well ~ Time extension ~ Change approved program Perforate 2. Name of Operator BP Exploration 3. Address P. 0. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 1726' NSL, 1130' WEL, SEC. 26, T12N, R15E, UM At top of productive interval 2289' NSL, 479' WEL, SEC. 26, T12N, R15E, UM At effective depth At total depth 2457' NSL, 362' WEL, SEC. 23, T12N, R15E, UM 12. Present well condition summary Total depth: measured true vertical Operation Shutdown__ Plugging X Pull tubing .,. Variance 5. Type of Well: Development Exploratory X Stratigraphic Service Re-enter suspended well X Stimulate Other 6. Datum elevation (DF or KB) KBE = 27.98'AMSL feet 7. Unit or Property name Prudhoe Bay Unit 8. Well number Niakuk #2A (23-12-15) 9. Permit number 76-79 10. APl number 50- 029-20180-01 11. Field/Pool Wildcat (Exploration) 12564' feet Plugs (measured) 10150' feet BKB Effective depth: measured true vertical 8204' feet Junk (measured) 7106' feet BKB Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Length Size Cemented Measured depth True vertical depth 20" 13-3/8" 9-5/8" 80 cu ft 78'MD RECEIVED 3906 cu ft 2714'MD 3050cuft 10997'MD JAN 08 19,91 (Niakuk #2) 7" 2156 cu ft 8297'-12564'MD "' "' ~ ~ - measured 12222'-12294' Reason for resuspension: To complete plug & abandonment operations for future reclassification to same. true vertical Tubing (size, grade, and measured depth) None Note: This well was drilled from the same surface location as Niakuk #2 (Abandoned). Kicked off at 8830'-8868'. Packers and SSSV (type and measured depth) None BOP sketch 13. Attachments Description summary of pro.~.~ ~! ._x__ Detailed operations program 14. Estimated date for commencing operation February 20, 1991 16. If proposal was verbally approved Date approved 15. Status of well classification as: Oil Gas~ Suspended x Service Name of approver 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed~'~,.~-~~'/' Title Completion Engineerin~t Supervisor Date ~//~:~ FOR COMMISSION USE ONLY Conditions of approval: N,otif¥ Commission so representative may witness ,. Plug integrity ~ BOP Test Location clearance _~_ Mechanical Infeg~ity Test Subsequent form required 10- Approved by order of the Commission BY 10NNIE C. SMITH ,~CS-mmissioner Date / --' Form 10-403 Rev 06/15/88 SUBMIT IN TRIPLICATE 1, 2. 3. 4. 5. . . . 10. 11. 12. 13. 14. 15. 16. 17. PGS 1/5/91 Niakuk 2A Re.suspension Procedure Notify an AOGCC representative prior to commencing operations. Remove ice and fill and in cellar to allow access to all wellhead equipment. Note wellhead and annulus pressures and bleed to zero if necessary. Remove 6" blind flange. Nipple up swab valve and tree cap. Rig up coiled tubing unit and circulate diesel out of well. Circulate out existing 10.4 ppg mud if mud quality deems it necessary. Lay a balanced cement plug, +150' in length, on top of bridge plug at 8204 ft. Rig down Coiled tubing unit. Wait on cement to set. Rig up wireline and tag top of plug. __T.~g..~_o be witnessed by AOGCC representative. Nipple down tree cap, swab valve and adapter flange. Stdp through 9-5/8" explosive cutter. Nipple up tree cap, swab valve, adapter flange and lubricator. Run in hole with explosive cutter and cut 9-5/8" casing 50' below surface. . Nipple down and pull 9-5/8" casing stub with crane. Nipple up adapter flange and swab valve. Rig up coiled tubing unit. Wash inside of 13-3/8" casing to 9-5/8" casing stub with hot diesel to clean out residual Arctic Pak. Run in hole to cement plug at +8054 ft and lay 10.4 ppg mud to 225' from surface. Lay permafrost grade ~~SLto_~,withi~,,n_ .25' from, surface (+13' below mudline). Rig down c611ed ~~~ unit and Wait on cembnt to'set. Cut and remove all casing strings and wellhead equipment to a minimum of 2 feet below mudline. Remove cellar and all man-made equipment to a minimum of 2 feet below mudline. Fill cellar area with gravel and grade. Remove all materials, supplie~, structures, and installations from location. Leave location in a clean and graded condition. I~I|AKUK ~2A PROPOSED POST SUSPENSION WELLBORE DIAGRAM CEMENT I0.4 PPG MUD CUT CASING STUBS (2 ft+ BELOW MUDLINE) CEMENT PLUG CUT 9-5/8" CASING STUB 20" CONDUCTOR 9 5/8" 47#/FT N-80 BTC CASING TIE-BACK CIRCULATING HOLES IN 9-5/8" CASING 9 5/8" CASING HANGER W/ PBR 13 3/8" 72#/FT N-80 BTC ~ KOP (DIR:NI.O'EMAX. ANGLE:46') CEMENT PLUG 9 5/8" EZ DRILL PACKER 7" LINER TOP 9-5/8" 47#/FT N-80 BTC (WI NDOW MI LLED ON BOTTOM SIDE OF 9-5/8" CASING IN NIAKUK ~2 TO SIDETRACK NIAKUK #2A) PBTD CEMENT PLUG HOWCO 7"EZ DRILL PACKER 7"29~/FT N-80 BUTT LINER PERFORATION DEPTH: 12222'- 12294' GWE/6-22-89 PGS I-5-91 KB Elev. = 27.98' AMSL I'JD (BKB) 47-247 FT 72 FT 78 FT 210OFT 2109FT 2714 FT 280O FT 8054-8204 FT 8204 FT 8297 FT 8830 FT 11894 FT 11894-12170 FT 12170-12177 FT 12564 FT NI AKUK =2A ~ELLBORE DIAGRAM ~ ,,~c'nc p^~ J~ cmrmr K~ Elev. - 27.98' APISL 2000 FT DIESEL L 20' CONOUCTOR 9 5/8' 47m/FT N-80 C~51NG TIE-BACK 9 ~/8' CAS1NG tIANGE. R W/ PeR 78 FT 2109 FT 10.4 PPG 'MUD ID ~/8' 72~"/FT N-80 OTC ~ ~:OP (DIR: NI.O'E flAX. ANGLE: 46') 2714FT 2600 FT ,. 9 5/8' EZ DRILL PACY. ER 8204 FT 7' LINER TOP 8297 FT 9-5/8' 47m/FT N-80 8TC (WINDOW MILLED ON 80TTCX'I SlOE OF 9-5/8' CASING IN NIAKUK "'2 TO SIDETRACK NIAKUK m2A) 8830 FT P§TD ' CIg"IENT PLUG HOWCO 7'EZ DRILL PACKER , 7' 2g'"/FT N-80 BUTT LINER , ,: PERFORATION DEPTiI: 12222'- 12294' GWE/6-22-S9 11894 FT 11894-12170 FT 12170-t2177FT 12564 IrT ,, t , ;. 41-,--. ' t . ~N~KUK No. Z~ I ' I " t I I hereby certify that I an~ properl7 registered I t~~ ~ preefi~ land K~ h the $t~ ~ .~atko un~r ~ ~Yte.l~, ond that all' dlmefllto~ end ~ D~te SURVEYOR AD~ED (PROPOSED) BOTTOM HOLE' · '. NIAKUK No. 2A .... s~rveyq~4t ter B.P. ALASKA INC. E M. LINDSEY ~ ASSOC. LA~D · HY~GR~HIC DEPARTMENT OF NATURAL RESOURCES DIVISION OF OIL AND GAS WA LTER ]. HICKEL, GOVERNOR P.O. BOX 7O34 ANCHORAGE, ALASKA 99510-7034 Iqiakuk/Pt. Mclntyre December 7, 1990 Terry J. Obeney, Manager Niakuk/Pt. Mclntyre, Alaska BP Exploration (Alaska) Inc. P.O. Box 196612 Anchorage, AK 99519-6612 RE: Oil and Gas Lease ADL 34625 Niakuk 2A Shut-in Production ACTION INFO LKB .------. -----.--- ASM ._..----- ------- WLB ...------ = ..... I~ES - ----- EHM -- -- JSO, ~ -- RWJ. , -- _ _ _ ,,, - -Copy , , CI~- _- .... File .... Dear Ms'. Obeney: In your letter of October 12, 1990 to Bill Van Dyke you described plugging and abandonment operations that BP Exploration is proposing for the Niakuk 2A well located on oil and gas lease ADL 34625. This well was certified capable of producing in paying quantities hi April 1977, and the lease has been held by shut-in production since that thne. You asked for confirmation that the proposal to remove the casing and wellhead below the mudline would not change the status of the lease. Paragraph 7 of the lease applies to an extension by shut-in production: If, upon thc expiration of the primary term or at any thne or tin~es thereafter, there is on said land a well capable of producing oil or gas in paying quantities, this lease shall not expire because Lessee fails to produce the same unless Lessor gives notice to Lessee allowing a reasonable time, which shall not be less than sixty days, after such notice to place the well on producing status, and Lessee fails to do so; providing, that after such status is established such production shall continue on the said land unless and until suspension of production is allowed by Lessor. If BP Exploration plugs and abandons the Niakuk 2A well, the state will retain the right to demand, on sixty days notice, that a well on ADL 34625 be placed on producing status. Should BP fail to meet this demand, the shut-in production paragraph of the lease will no longer hold the lease. Regardless of whether the lease is held by shut-h~ production, ADL 34625 is committed to the Pmdhoe Bay Unit Agreement, and the lease term will continue to be extended, h~ accor(hmce with oil and gas lease regulation 1'1 AAC 83.190, for as long as the lease remah~s subject to the Unit Agreement. ADL 34625 Niakuk 2A Shut-in Production Page 2 This lease was scheduled for contraction from the unit area on April 1, 1987. A delay of mandatory contraction of the Pmdhoe Bay Unit with respect to ADL 34625 was approved on February 25, 1987. If the lease is not committed to a participating area by April i, 1992, it will be contracted out of the Prudhoe Bay Unit. Give me a call if you have any further questions. S inc/e, rely, 47. Jarr~s E. Eason Director 3585t/cdw STATE OF ALASKA ADL 34630 ~ AL~,,~A OIL AND GAS CONSERVATION CO,...41SSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon[3 Suspend Operation Shutdown [] Re-enter suspended well CJ AltercasingI3Ohr Time extension I~ Change approved program [] Plugging [] Stimulate [] Pull tubing [] Amend order ~ Perforate 2. Name of Operator Standard Ala,~ ka 3. Address P. O. Box 196612, Anchorage, Alaska 99519-6612 4. location of well at surface 1726' NSL, 1130' WEL, Sec. 26, T12N, R15E, UM At top of productive interval 2289' NSL, 479' WEL, Sec. 26, T12N, R15E, UM At effective depth At total depth 2457' NSL, 362' WEL, Sec. 23, T12N, R15E, UM 5. Datum elevation (DF or KB) KBE - 27_98' _z_lv[Sr_ 6. Unit or Property name Prudhoe Bay Unit 7. Well number NIAKUK #2A(23-12-15) feet 8. Permit number 76-79 9. APl number 50-029-20180-01 10. Pool Wildcat 11. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical 12564 feet 10150 feet 8204 feet 7106 feet Plugs(measured) Kick off plug in 9-5/8" 10025' 7" EZ Drill Bridge Plug 12170'. Topped w/55 cu. ft. cement. 9-5/8" Bridge Plug 8204'. Casing Length Size Structural Conductor 20" Surface 13-3/8" Intermediate 9-5/8" Production 7 °' Liner Perforation depth: measured 12222 '-12294' true vertical Tubing (size, grade and measured depth) Cemented Measured depth 80 cu.ft. 78'MD 3906 cu.ft. 2714'~D 3050 cu.ft.(Niakuk #2) 10997'HD 2156 cu.ft. 8297'-12564'MD None Packers and SSSV (type and measured depth) None ~ 12.Attachments Description summary of proposal [] Detailed operations program 13. Estimated date for commencing operation True Vertical depth Reason for extension: This suspended well is being considered for future testing in the Niakuk development area. Note: This well was drilled from same surface hole as Niakuk #2 (abandoned). Kicked off and sidetracked at 8830'-8868'.. BOP sketch 14. If proposal was verbally approved Name of approver Date approved 15. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ¢, ~. ~ TitleDivision Drilling Engineer Commission Use Only Date Conditions of approval Notify commission so representative may witness I Approval No. [] Plug integrity [] BOP Test [] Location clearance 7~,~'-3 / Approved by Form 10-403 Commissioner by order of the commission Date ,~- Sub'net' in triplicate -- ADL 34630 STAT E OF-'AL~AS KA ALAoKA OIL AND GAS CONSERVATION COIV~v~ISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon i~} Suspend ['] Operation Shutdown i , Re-enter suspended well ; i Alter casing ; . Time extension [X Change approved program :i-! Plugging E~ Stimulate '.' Pull tubing ',: Amend order [ i Perforate ', Other ' '. 2. Name of Operator Standard Alaska Production Company 3. Address P. O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 1726' NSL, ll30' HEL, Sec. 26, T12N, R15E, UM Ata~OsO9~f r, duct' it I ~1~)~, ~vle9¢~i~., Sec. 26, T12N, RlSE, UM At effective depth A~2~::)]C~l'd~::)~[~, 362' 14EL, Sec. 23, T12N, R15E, UH 5. Datum elevation (DF or KB) KBE = 27.98' AMSL 6. Unit or Property name Prudhoe Bay Unit 7. Well number NIAKUK #2A(23-12-15) 8. Permit number 76-79 9 APl r 8o-o 10. Pool Nildcat feet 11. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical 12564 10150 feet feet 8204 feet 7106 feet KiP~l(gst)ff~eaps~)in 9-5/8" 10025' 7" EZ Drill Bridge Plug 12170' Topped w/58 cu. ft. cement. 9-5/8" Bridge Plug 8204'. Casing Length Structural Conductor Surface Intermediate Production Liner Perforation depth: measured 12222'-12294' true vertical Size 20" 13-3/8" 9-5/8" 7" Tubing (size, grade and measured depth) None Packers and SSSV (type and measured depth) None Cemented Measured depth 80 cu.ft. 78'MD 3906 cu.ft. 2714'MD 3050 cu.ft.(Niakuk #2) 10997'MD 2156 cu.ft. 8297'-12564'MD True Vertical depth Reason for extension: This suspended well is being considered for future testing in the Niakuk development area. Note' This well was drilled from same surface hole as Niakuk //2 (abandoned). Kicked off and sidetracked at 8830'-8868'. 12.Attachments Description summary of proposal Request extension under 20 AAC. 2.g_17f~(b) 13. Estimated date for commencing operation BOP sketch 14. If proposal was verbally approved ~1¢ ....... Date 'aDp'roved Name of approver '*' ,,"-' 0i! & 0[;i., 15. I hereby certify that the foregoing is true and correct to the best of ~¢"Rnowledge Signed ~ ~. ¢. ~ Title Division Drilling Engineer Commission Use Only Date Conditions of approval ! Notify commission so representative may witness I Approval No./g-w,/ L.~ Plug integrity ~} BOP Test [_-~ Location clearance Form 10-403 Rev 12-1-85 Commissioner by order of /~)¢/'~ the commission Ddt ¢'ubrr~ in triplicale Telecopy No. (907) 276-7542 August l, 1986 Mr. R. S. Allan ~'~ Division Drilling Engineer Standard Alaska Production Company P. O. Box 6612 Anchorage, AK 99502-0612 Re: Extension of Susu~ended Status Niakuk No. 1-A Niakuk No. 5 ..Niakuk No. 2-A Sag Delta No. 9 Niakuk No. 4 Sag Delta No. 10 Dear Mr. Allan: A review of our records shows that the above referenced wells are suspended. Section ll0(a) of the regulations states the Commission will, in its discretion, approve the suspension of a well if the well is capable of producing hydrocarbons in paying quantities or is reasonably demonstrated to have future value as a service well. Section 105(d) states: "Each well drilled from a beach or from an artificially constructed island or a shifting natural island must be abandoned or suspended before removal of the drilling unit from the site unless completed as an oil, gas or service well...~ and plans for maintaining the integrity of the well site are approved by the Commission." In compliance with Section 172(c) of the regulations, "If]or a well abandoned from an artificial gravel island or a shifting natural island, the well site must be cleared within one year following abandonment, or before the time that the operator ceases to conduct activities necessary to ensure the integrity of the well site .... " Section ]05(m) provides the means for obtaining "...a variance from the requirements of this section if the variance equally effects proper plugging of the well and will not allow the movement of fluid into sources of hydrocarbons or freshwater." Mr. R. S. Allan August 1, 1986 Page 2 We are, therefore, requesting that you submit Form 10-403, Application for Sundry Approval, for a one-year extension of suspended status for the above .referenced wells together with justification for keeping the wells in suspended status. Please call Harold J. Hedlund at 279-1433 if you have any questions. Sincerely, Lonnie C. Smith Commiss loner jo/A.HJH. 23 SOHIO ALASKA PETROLEUM COMPANY 900 EAST BENSON BOULEVARD ANCHORAGE, ALASKA TELEPHONE (907) 561-5111 P.O. BOX 6612 ANCHORAGE, ALASKA 99502~3612 July 22, 1985 Mr. C.V. Chatterton Alaska Oil -& Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 RE- 1985 LOCATION INSPECTION Dear Mr. Chatterton' In compliance with State Regulation 20 AAC 25.170, attached are Forms 10-403, Sundry Notices and Reports on Wells, for the following wells. These notices request that the wells remain in suspended status. Sag Delta Sag Delta Sag Delta Sag Del Sag Del Sag Del Sag Del Sag Del Niakuk Niakuk BP 41-33-12-1 3 BP 22-33-11-13 Term Well B (22-20-11-13) Term Well C (34-03-11-12) Chevron Tract Well (23-18-11-12) MPC Tract Well (21-03-10-12) PBU MP 43-31-11-13 MPC 11 - 33-11-12 Getty State #1 (02-10-13) MP Tract Wel 1 (32-30-11-13) PBU MP (22-31-11-13) No. 2 West Sak 25645 #9 West Sak 25548 #11 West Sak 25655 #14 West Sak #16 West Sak #17 Kuparuk State 22-11-12 Sag Delta #1 (33-12-16) #2A (10-11-16) #3 (35-12-1 6) 34633 #4 ta #5 (36-12-15) ta #7 ta #8 ta #9 ta #10 #lA {26-12-1 5) #2A (23-12-1 5) Alaska Island #1 Ni akuk #4 Niakuk #5 P ECc' D 60,, ,~,,~,~,r~ Alaska Oil & Gas Con:;. '~' ...... '~ Anch3rag3 Mr. C.V. Chatterton July 22, 1985 Page 2 Sag Delta #11 is now ready for final inspection of the abandoned wel 1. Please advise the undersigned which day during the week of August 19-23 is acceptable for your field inspector to accompany our representative for this annual location inspection trip. Very truly yours, RSA/CRM/sh 72285:0530N Attachments cc' Well File #17 R.S. Allan Acting SAPC Drilling Engineer STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL [] OTHERk~ 2. Name of Operator 7. Permit No. Sohio Alaska Petroleum Company 76-79 3. Address 8. APl Number Pouch 6-612, Anchorage, Alaska 99502 50- 029-20180-01 9. Unit or Lease Name 4. Location of Well At surface: 1726' NSL, 1130' W'I~, SOC. 26, T12N, R15E, UPM 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. KBE = 27.98 ' AMSL I ADL 34625 12. 10. Well Number Niakuk #2A (23-12-15) 11. Field and Pool Wildcat (Exploration) Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: Request extension under SUBSEQUENT REPORT OF: (Submit in Triplicate) 20 AAC 25.170 (b) 1,2,3 (Submit in Duplicate) Perforate [] Alter Casing [] Perforations [] Altering Casing [] Stimulate [] Abandon [] Stimulation [] Abandonment [] Repair Well [] Change Plans [] Repairs Made [] Other [] Pull Tubing [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). Reason for extension: This site is being considered for future Exploration and/or development. Note: This well was drilled frcm same surface hole as Niakuk #2 (abandoned). Kicked off and sidetracked at 8830' - 8868'. / 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~ ~--~ - ~ Title District Drilling Engineer The space below for Commission use R. H. Reiley r-t-~-, ,~,~ed Copy Conditions of Approval, if any: HT [OMNIE C. S}~ITH By Order of Approved by COMMISSIONER the Commission Returned Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate SOHIO ALASKA PETROLEUM COMPANY 3111 "C" STREET, ANCHORAGE, ALASKA TELEPHONE (907) 561-5111 MAIL: POUCH 6-612 ANCHORAGE, ALASKA 99502-0612 July 10, 19 84 Mr. C. V. Chatterton Alaska Oil & Gas Conservation Cc~m%ission 3001 Porcupine Drive Anchorage, Alaska 99501 Re: 19 84 LOCATION INSPECTION Dear Mr. Chatterton: In oompliance with State Regulation 20 AAC 25.170, attached are Forms 10-403,' Sundry Notices and Reports on Wells, for the follcwing wells. These notices request that the wells remain in suspended status o BP 41-33-12-13 BP 22-33-11-13 Te~m Well B (22-20-11-13) Term Well C (34-03-11-12) Chevron Tract Well (23-18-11-12) MPC Tract Well (21-03-10-12) PBU MP 43-31-11-13 MPC 11-33-11-12 Getty State #1 (02-10-13) MP Tract Well (32-30-11-13) PBU MP 22-31-11-13) No. 2 West Sak 25645 #9 West Sak 25548 #11 West Sak 25655 #14 West Sak #16 West Sak #17 Kuparuk State 22-11-12 Sag Delta #1 (33-12-16) Sag Delta #2A (10-11-16) Sag Delta #3 (35-12-16) Sag Delta 34633 #4 Sag Delta #5 (36-12-15) sag Delta #7 Sag Delta #8 Sag Delta #9 Sag Delta #10 Niakuk #lA (26-12-15) Niakuk #2A (23-12-15) Alaska Island #1 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL [] 2. Name of Operator 7. Permit No. Sohio Alaska Petrole~ Ccmpany 76-79 3. Addres~ 8. APl Number Pouch 6-612, Anchorage, Alaska 99502 so- 029-20180-01 9. Unit or Lease Name OTHER3[3 4. Location of Well At surface: 1726' NSL, 1130' ~L, Sec. 26, T12N, R15E, UPM 5. Elevation in feet (indicate KB, DF, etc.) ! 6. Lease Designation and Serial No. I 34625 [~R~. = 27.98 ' N45r__. . 10. Well Number N~ ff2~ (23-12-15) 11. Field and Pool Wildcat (Expl~ratic~) Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: ~qt~-st exteru~icx~ ~ncl~_~ SUBSEQUENT REPORT OF: (Submit in Triplicate) 20 A/~ 25.170 (b) 1,2,3 (Submit in Duplicate) Perforate I'-] Alter Casing [] Perforations [] Altering Casing [] Stimulate [] Abandon [] Stimulation [] Abandonment [] Reoair Well [] Change Plans [] Repairs Made [] Other [] Pull Tubing [] Other ~ Pulling Tubing [~] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work. for Abandonment see 20 AAC 25.105-170). Reason for extensic~: This site is being considered for future Exploration ar~or dev~lo~.nt. Note: This w~ll was drilled frcm same surface hole as N~akuk #2 (abandoned). Kicked off and sidetracked at 8830' - 8868'. , , i The space b~ow for Commiui0n use ". Ho ~.,. e~_ k Condilionl ot Apl3rOval, if tny: AI3groved by ~pproved Copy Returned Suspended status is extended until September, 1985. _~.~, . Submi! "Intentions" in Triplicate Form 10-403 FROM: EMORAN DUM State of Alaska ALASLI<A ' CI ~D CAS Chai~an---~%~" ~ . .~;~ ~'j""' FILE NO: 1 O gA: ~nnie C. S~ith // Commis s loner TSLEPHO~E NO: Edgar W. Sipple, J~/~ SUSUECT: Petroleum Inspecto~ Inspecton on Sohio' Sus L~nded Locations I, isted Delow. Tuesday, August 9, 1983: I traveled this date with [..like DiDger, Sohio's representatiave, to look at the susl~ended locations listed below: ~iakuk lA (26-12-15) ~iakuk 2A (23-12-15) Te~ ¥¢ell D Ter~,., ~Vel 1 C Kuparuk 22-11-12 State fl (2-10-13) Attached to this report are pictures of the well head, drillin,~ pa¢~s, reserve pits, and'a coFY of the AOCCC surface susl~nsion location report. It is my reccr~,Pendation to the Commission that the aLovc loca- tions k,e accepted in regards to location cleanup, %-~,ell sign placement, and. pit conditions, with the e×cel;tion of 22-1~-12, after the pallets and 2 x 4's are rer,.:oved from this location, appr,?ve this location. Atta ch~ents Suspended Well and Location Report 20 AAC 25, ARTICLE 2 FILE INFORMATION:~ /2 ,,1/' ~ . ~"~n I~ ~ 0pe~a~0r ~_~.~. ~/~ ~ ~ ~_~[~ . Date SuSpended ~~ Address ~~ 6~_/~]~/~~~~~ .~~ ' Surface ~cati6n of Wel-i ...... z z---~ Pe~it N0~ ~ ~ ~-[~;~C- ~ ~ / ~J6 Ft. F ~ L, 11,%O Ft. F~L API No. 50-R3~-~0/~.--/_ Sec. ' Unit or Name oM Field ~ Pool U3, ~~~. - ...... Condition of Pad . _.~..~..(. _ Condition of Pits Well head - Ail outlets plugged Wel 1 sign - Attached to well head Attached to Information correct Yes No Y s No ~~ No No Cellar - Opened Yes No Rat Hole ~~) No Ye s ~ ~ Fi'l led Ye s No (~~[~ No Covered Yes No WaterWell - Plugged off Capped Open Exp la na ti on Photographs taken to verify above conditions Yes No Explanaton Work to be done to be .acceptable This well and location is (acceptable) suspended for the period of Date: (~na-ec=~.~) to be cla.ssified as 19 thru 19 . Revised 8/24/82 JA SOHIO ALASKA PETROLEUM COMPANY 3111 "C" STREET ANCHORAGE, ALASKA TELEPHONE (907) 276-51 MAIL: POUCH 6-612 ANCHORAGE, ALASKA 99502 July 21, 1983 Mr. C. V. Chatterton Alaska Oil & Gas Conservation ODnmzission 3001 Porcupine Drive Anchorage, Alaska 99501 1983 LOCATION INSPECTION Dear Mr. Chatterton: In compliance with state Regulation 20 AAC 25.170, attached are Forms 10-403, Sundry Notices and Reports on Wells, for the following wells. These notices request that the wells remain in suspended status. BP 41-33-12-13 BP 22-33-11-13 Term Well B (22-20-11-13) Term Well C (34-03-11-12) Chevron Tract Well (23-18-11-12) MPC Tract Well (21-03-10-12) PBU MP 43-31-11-13 MPC 11-33-11-12 Getty State .#1 (02-10-13) .MP Tract Well (32-30-11-13) PBU ~P 22-31-11-13, No. 2 West Sak 25645 #9 West Sak 25548 #11 West Sak 25655 #14 West Sak #16 West Sak #17 Kuparuk State 22-11-12 Sag Delta #1 (33-12-16) Sag Delta #2A (10-11-16) Sag Delta #3 (35-12-16) Sag Delta 34633 #4 Sag Delta #5 (36-12-15) Sag Delta #7 Sag Delta #8 Sag Delta #9 Sag Delta #10 Niakuk #LA (26-12-15) Niakuk #2A (23-12-15) Alaska Island #1 Mr. c. v. Chatterton July 21, 1983 Page Two Water Injection Well GC - lB (13-11-13) is also now ready for final inspection of the abandOned well site. Please advise the undersigned which day during the week of August 8th is acceptable for your field inspector to accompany our representative for this annual location inspection trip to the above-named well sites. Very truly yours, R. H. Reiley District Drilling Engineer encs cc: Well Files #17 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL [] OTHERkE] 2. Name of Operator 7. Permit No. Sohio Alaska Petroleum Company 76-79 3. Address 8. APl Number Pouch 6-612, Anchorage, Alaska 99502 50- 029-20180-01 4. Location of Well 9. Unit or Lease Name At surface: 1726' NSL, 1130' WEL, Sec. 26, T12N, R15E, UPM 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. KBE = 27.98 ' AMSL I ADL 34625 12. 10. Well Number Niakuk ~2A (23-12-15) 11. Field and Pool Wildcat (Exploration) Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO' Request extension under SUBSEQUENT REPORT OF: (Submit in Triplicate) 20 AAC 25.170 (b) 1,2,3 (Submit in Duplicate) Perforate [] Alter Casing [] Perforations [] Altering Casing [] Stimulate [] Abandon [] Stimulation [] Abandonment [] Repair Well [] Change Plans [] Repairs Made [] Other [] Pull Tubing [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). Reason for extension: This site is being considered for future Endicott Reservoir development. Note: This well was drilled from same surface hole as Niakuk #2 (abandoned). Kicked off and sidetracked at 8830' - 8868'. Returned 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. The space below for Commission use R. H. l:~iley Date Conditions of Approval, if any: This location was inspected by our representative on August 9, 1983 and clean up was found satisfactory for a suspended location. A subsequent inspection will be necessary by August 1984. ORIGINAL SIGNED ?'f' LONNIE C. SMITH ByOrder of Approved by COMMISSIONER the Commission Date Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate MEMOF ,NDUM of Alaska ALASKA OIL AND GAS CONSERVATION COMMISSION TO:c. V. Chatterton Chairman Thru: Lonnie C. Smith Commissioner DATE: November 9, 1982 FILE NO: 108/A TELEPHONE NO: FROM' Doug Amos Petroleum Inspector SUSJEGT: Inspection of Sohio' s Suspended Locations Listed Below Friday_, August .2_7, 1982 - I traveled this date to Prudhoe Bay where I met Jerry Segar, Sohio representative, and conducted the second clean-up inspection on the locations listed below. Attached to this report are pictures of well heads, reserve pits, drilling pads and a copy of the Form 10-403. I recommend to the Commission that the following locations be accepted in regard to location clean-up, well sign 'placement, and pit condition. PBU MP 22-31-11-13 No. 2 Term Well ~ (22-20-11-13) Term Well C (34-03-11-12) MPC Tract Well 21-03-10-12 · . MPC 11-33-11-12 Getty State No. 1 (2-10-13) PBU MP 43-31-11-13 West Sak 25645 #9 (3-11-9) West Sak 25548 #11 (36-12,8) West Sak 25655 #14 West Sak #16 (31-36-13-08) West Sak #17 (44-2'6-13-09) Kuparuk State 22-11-12 Sag Delta #5 (36-12-15) Sag Delta #1 (33-12-16) No pictures, ran out of film · Sag Delta #2A (10-11-16) " " " " " " II II !1 II II II II II II II II II I! II II II I! II Sag Delta #3 (35-12-16) " " Sag Delta .#4 (34633) " " Sag Delta #7 " " Sag Delta #8 " " Sag Delta #9 " " " Sag Delta #10 " ". MP Tract Well 32-30-11-13" " Niakuk %lA (26-12-15) Niakuk #2A (23-12-15) Chevron Tract Well (23-18-11-12) In summary, I inspected the above listed suspended locations for clean-up, well signs, and pit conditions. 02-001 A(Rev.10/79) Susp~-~ed Well and Location 20 LAC 25, ARTICLE 2 Repc~-t FILE INFORMATION: Operator ~_~~ Addre s s Date Suspended Surface Location of Well Permit No. ~~__Ft.~-_~~n, //-~O Ft. '~z~ n API No Sec.___~, T3/~ .~/ , $/~_~_, ~M. Unit or Lease Name Wel 1 No; COndition of Pits _ _ .~j/~ /-- Well head - Ail outlets plugged Wel 1 sign - Attached to well head Attached to well guard Attached to Information correct No Ye s ~' ~~ NO Cellar - Opened 'Filled Covered · WaterWell - Plugged off Yes ~ . Rat Hole Open C~S~ N o F i 1 led ~e~go N o C o ve r e d Exp la na ti on Ye s No No Photographs taken to verify above conditions ~ No Explanaton Work to be done to be acceptable . This well and location is (a_c~p~a?) (unacceptable) to be suspended for the period' of _~~7_~ _ l~thru Inspected by: ~:~.~? ~ .... ~ ~ / Revised 8/24/82 classified as 19 ~3 · SOHIO ALASKA PETROLEUM COMPANY 3111 "C" STREET ANCHORAGE, ALASKA TELEPHONE (907) 265-0000 MAIL: POUCH 6-612 ANCHORAGE, ALASKA 99502 July 30, 1982 Mr. C. V. Chatterton Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Chatterton: In compliance with State Regulation 20 AAC 25.170, attached are Forms 10-403, Sundry Notices and Reports on ~.Vells, for the following wells. These notices request that the wells remain in suspended status o BP 41-33-12-13 BP 22-33-11-13 Tern Well B (22-20-11-13) Term Well C (34-03-11-12) Chevron Tract Well (23-18-11-12) MPC Tract ~4ell (21-03-10-12) PBU MP 43-31-11-13 MPC 11-33-11-12 Getty State #1 (02-10-13) MP Tract Well (32-30-11-13) PBU MP 22-31-11-13, No. 2 West Sak 25645 #9 West Sak 25548 #11 West Sak 25655 #14 West Sak #16 West Sak #17 Kuparuk State 22-11-12 Sag Delta #1 (33-12-16) Sag Delta #2A (10-11-16) Sag Delta #3 (35-12-16) Sag Delta 34633 #4 Sag Delta #5 (36-12-15) Sag Delta #7 Sag Delta #8 Sag Delta #9 Sag Delta #10 Niakuk #IA (26-12-15) Niakuk #2A (23-12-15) Alaska Island #1 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION CO~MISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL [] 2. Name of Operator 7. Permit No. Sohio Alaska Petroleum Company 76-79 3. Address 8. APl Number Pouch 6-612, Anchorage, Alaska 99502 50- 029-20180-01 9. Unit or Lease Name OTHER E~ 4. Location of Well At surface: 1726' NSL, 1130' WEL, Sec. 26, T12N, R15E, UPM 5. Elevation in feet (indicate KB, DF, etc.) KBE = 27.98' AMSL 6. Lease Designation and Serial No. ADL 34625 10. Well Number Niakuk #2A (23-12-15) 11. Field and Pool Wildcat (Exploration) 12. Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: Request extension under SUBSEQUENT REPORT OF: (Submit in Triplicate) 20 AAC 25.170 (b) 1,2,3 (Submit in Duplicate) Perforate [] Alter Casing [] Perforations [] Altering Casing [] Stimulate [] Abandon [] Stimulation [] Abandonment [] Repair Well [] Change Plans [] Repairs Made [] Other [] Pull Tubing [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). Reason for extension: This site is being considered for future Sag Delta development Clean-up to date: a) Major structures have been removed. b) Loose debris has been removed. Note: This well was drilled from same surface hole as Niakuk #2 (abandoned). Kicked off and sidetracked at 8830' -. 8868'. 14. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~ The space bel i].ey Approved Cop'/ Returned / / , Title District Drilling Engineer 7'30 Date Conditions of Approval. if any:This location was inspected by our representative on August 27, 1982 and clean up was found to be satisfactory for a suspended loctioan. A subsequent inspec- tion will be necessary by August 1983. Approved by ~!~' ,.~., ,',-' ~ ~]T By Order of 2-- __ ,,~!:~.i~_~ ~ ........ .~..~ COMMISSIONER theCommiss,on Date Form 10-403 Submit "Intentions" ,n Tr~pl,cate STATE OF ALASKA ALASKA£ AND GAS CONSERVATION CC VIISSION SUNDRY NOTICES AHD REPORTS OH WELLS 1. DRILLING WELL [] COMPLETED WELL [] OTHER [] 2. Name of Operator Sohio Alaska Petroleum Company 3. Address Pouch 6-612, Anchoraqe, Alaska 4. Location of Well At surface: 99502 1726' NSL, 1130' WEL, Sec. 26, T12N, R15E, UPM 5. Elevation in feet (indicate KB, DF, etc.) KBE = 27.98' AMSL I6. Lease Designation and Serial No. ADL 34625 7. Permit No. 76-79 8. APl Number 50-029-20180-0] 9. Unit or Lease Name 10. Well Number Niakuk #2A (23-12-15) 11. Field and Pool Wildcat (Exploration) 12. Check Appropriate Box To Indicate Nature of Notice, Report, o NOTICE OF INTENTION TO: Request e×tensior] uric]er (Submitin Triplicate) 20 AAC 25.170 (b) 1,2,3 Perforate [] Alter Casing [] ~ Perforations Stimulate [] Abandon [] Stimulation Repair Well [] Change Plans [] Repairs Made Pull Tubing [] Other [] Pulling Tubing (Note: Repor't multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) Other Data SUBSEQUENT REPORT OF: (Submit in Duplicate) [] Altering Casing [] Abandonment [] Other [] [] [] 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of s,tarting any proposed work, for Abandonment see 20 AAC 25.105-170). Reason for extension: This site is being considered for future Sag Delta development. Clean-up to date: a) Major structures have been removed. b) Loose debris has been removed. NOTE: This well was drilled form same surface hole as Niakuk ~2. Kicked off and sidetracked at 8830'-8868'. Approved Copy_ Returned 14. I hereby~n_q is trL~'~nd correct tO the best of my knowledge. Signed (~ ~ ~ ~~ , TitleDiStrict Drillir~j Enqineer Date The space below f~sion use R. H. l~ey Conditions of Approval, if any: This location was inspected by our representative on September 2, 1981 and the clean-up was found to be acceptable. Approval is given to leave the well head on, the cellar open, and th,e ri~ support timbers in place This is given ^ inspect ion subsequent Approved~¥ be neces ~~6N914d,~rl~Fon1982 Da,e ........ Form 10-403 ORIG!NA[ SIGN[I} Rev. 7-1-80 lJV I flM~IIL' r Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate 02 OO lB IRev STATE of ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION to: ~Hoyle H. Hamilton//J~/F Chairman Thru: Lonnie C. Smith~l Commissioner FrOm: Bobby Foste~.J~ -. Petroleum Inspector DATe: September 11, 1981 FILE NO TELEPHONE NO suBJect Inspection of SOHIO's Suspended Locations Listed Below ~r Monday August 31 Thru Wednesday September 2: I traveled to Prudhoe Bay Monday August 31, 1981 where I met with Jack Barr, Judy Golding and Jerry Stegar, Sohio representatives and discussed the upcoming location inspection. Attached to this report are pictures of well heads, reserve pit, drilling pad, and a copy of surface suspension report. It is my recommendation to the commission that the following locations be accepted in regard to location clean-up, well sign placement, and pit condition. Mobil Phil lips Mobil Phil lips Mobil Phil lips Chevron Tract West Sak West Sak West Sak West Sak Mobil Phil lips Mobil Phil lips Mobil Phil lips Term wel 1 Term wel 1 Getty State Niakuk Niakuk Niakuk Ni akuk Sag Delta Sag Delta Sag Delta Sag Delta Sag Delta Sag Delta Sag Delta 21-03-11-12 11-33-11-12 22-11-12 23-18-11-12 #9 #il #16 22-3i-ii-i3 43-31-11-13 32-30-11-13 B C #1 #1 #lA #2 #2A #1 #2 #2A #3 #4 #8 In summary, I inspected the above listed suspended locations for clean-up, well signs, and pit conditions. 2 FILE [NFOI(r.I,\'FiON: ~, Surface Location of 2 0 AAC 2 5 1 2 0: WELL ,\~':~,-~,%~'[' ;',,\ .... 7- · , t', r,,',I',: Dia. Steel Post (4"Min.)_ ~,,~'~' '.<:; /.~.,: , Height Above Final Gra¢te Level~ (4' Top of Harker Pipe Closed with' Cement'Plug Set: On Well }lead ,' On Cutoff C;~sing Distance Below Final Grade Level Side Outlets: All Valves and ~.~[pp]es Re~noved All Openings CloSed c_ With Lengtt~ (10' Hin.) I')/ ' Screw (in1) Concrete PI ~g Ft. in, With Cement (List hq~ere Different from File info~:maLion) Ope ra to r /b/ /? , ,, / /~ [:nit or l,~a~e Name Well Number / , Surface Location of WelL: Ft. F L, Ft., F L, ,Sec , T , 20 AAC 25.170: LOCATION CLEAU-UP .- Filled Iai2:'- , Liners Removed or B~rLed , Debris Removed SURFACE OF P~ A:O/OR Rough , Smooth ~+-:, Contoured , Flat , Compacted Other CLEAN UP OF PAD Al:D/OR Clean ~' ....... , Pipe Scrap Paper , Other , __, Iron Sc~;il~;__, Wood __, Hud Welds , (~emt2n [ , SURROUNI)ING ARE,\: Wooded Brush , Tundra , Grass , Dirt , (;ravel Sand ., 'Other CONI) ['[' IO.N SUIt P, OLINI) [.N(; ,\I', F,,\: Clean ~..--' , Trash from Site Other ACCESS ROAD: Dirt'-:' /- Gravel Ice Otl~er CONI)[TION ACCESS ROAD AND C'leanz';:.:.~,:.., Rough __, Smooch Trees and/or Brush from Clearing Road Other , St)oil from Cluarizig Road RE~LA1N1NG TO BI'; DOEE: /.?>" " RECOHHI':NI) AI)PROVAL OF t~J')O::[~h~llf:Nzf: Yes ,~: , INSPECTED BY * ': ~, ' A :..-. %/f:~ ~ ';C'~:' 05/2 6/81 / ~ N o i:i~a 1 Inst)ec tioa :'r: , --/-' o~u/g;x~Z' ~I .! SOHIO ALASKA PETROLEUM COIVlPANY August 17, 1981 Mr. Lonnie Smith Alaska Oil & Gas Conservation Coumission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Smith- In compliance with State Regulation 20 AAC 25.t70, attached are Forms 10-403, Sundry Notices & Reports on Wells, for the following wells. These notices request that the wells remain in suspended status. Term Well B (22-20-11-13) Term Well C (34-03-11-12) Chevron Tract Well (23-18-11-12) MPC Tract Well (21-03-10-12) PBU MP 43-31-11-13 MPC 11-33-11-12 Getty State #1 (02-10-13) MP Tract Well (32-30-11-13) PBU MP 22-31-11-13, No. 2 West Sak 25645 #9 West Sak 25548 #11 West Sak 25655 #14 West Sak #16 West Sak #17 Kuparuk State 22-11-12 Sag Delta #1 (33-12-16) Sag Delta ~2 (10-11-16) Sag Delta #2A (10-11-16) Sag Delta #3 (35-12-16) Sag Delta 34633 #4 Sag Delta #5 (36-12-15) Sag Delta #7 Sag Delta #8 Niakuk #1 (26-12-15)-abandoned Niakuk #iA (26-12-15) Niakuk #2 - abandoned Niakuk #2A (23-12-15) / .~ Niakuk #3 (t3-12-15) Mr. Lonnie Smith August 17, 1981 Page Two We would like to have your field inspector present sc~eti~ during the week of August 31 - September 4 to accc~pany our representative for final location inspection of the following wells: Challenge Island #1 Reindeer Island Stratigraphic Test #1 West Sak #4 Kemik Unit #2 West Kuparuk State 3-11-11 Hurl State 5-10-13 Socal-Mobil 33-29E (29-12-11) Kuparuk State 33-11-12 Kuparuk 9-11-12 MPC 7-11-12 Kuparuk State 21-11-12 MPTract Well 13-15-11-12 PPJ:JLG: ja Attachments cc: Well Files CC# 37,291 Yours very truly, P. R. Judd Manager Drilling June 4, 1981 Sohio Alaska Petroleum Comma.ny Pouch 6-612 Anchorage, Alaska 99502 Re: Alaska Oil and gas Conservation Commission Regulations Article 2, AEADDONMENT A~D PLUGGING, 20 AAC 25 120 WELL · ~.o~.r~,,,~.~.:=,...~.~ MARKER and 20 AAC 25.170 LOCATION CLEAI'? UP. Gentlemen: In regard to the above referenced regulations, your attention is called to an attached list of wells which, according to our records, have not received, a final location insL~ection and approval of clean up. In compliance with 20 AAC 25.170 Section (a), "Within omc year of suspension or abandonment of an on- shore well", all clean up work is to be finished. Section (b) provides the means for an extension of time if a valid resson exists. Section (c) provides for on site inspection. Consequently, we are presenting the following list of your abandoned and/or suspended wells.~..~any of these are now more than one year old and are not in compliance with regulations. utners should have the final inspection completed this summer while weather permits. This list covers the years 1975 to date. There may be some earlier wells that also need inspec- tion. if you have a~~.~. earlier wells to be ins]?ected this summer please inform us. Therefore, we are requesting a schedule from you for this sumner when our field inspectors can accompany your z'epresenta- tives to these sites for the final clean up inspection. LC$/JKT: be SOHIO ALASKA PETROLEUM COMPANY SUSPENDED Kuparuk 22-11-12 Niakuk #1-A Niakuk #2 Niakuk #2-A Niakuk #3 Prudhoe Bay Unit 3-10-12 Sag Delta #2 Sag Delta #3 Sag Delta #33-12-16 Sag Delta 28337 #2-A Sag Delta 34633 #4 W. Sak 25519 ~17 W. Sak 25548 #11 W. Sak 25645 49 W. Sak 25655 #14 (GETTY, SOHIO, OPR.) State #1 PLUGGED & ABANDONED Challenge Is. #1 Niakuk #3 Prudhoe Bay Unit Nomination 1 RD Prudhoe Bay Unit TR 15-11-12 Reindeer Is. Strat Test 91 W. Sak 25667 #4 (BP/SOHIO) K~mik Unit Niakuk # 1 ' ttlOinlCFi :abject: -~te: -~o date: 'ontact: .,none: NOYE TO EDITORS: If you need to conhact anyone in SOHIO on ~the attached release, call Roger Herrera, Operations }~anager-~loration, at 265-0474. The pL'oduc.'[.ng gone for these wells is bc~.ieved to be conL.inuous chat ancounte, xed in Duck Island wells {~1 and {[iZ previously by Ex×on in a press re. lease by that company in October 1980. An eak-tIc, r Sohio ve:tical well, Sag Delta {'~3, da-illed in 1977 to 11~779 fL, o~ tl~a seine island as Sag Delta ~j4, t~_ad oil and bit~mmn i~d.tc.ations but. tested water. . "'~ ~ ~ l,t.:lgati(;n was brought cn.,].lenglng the validity of the December 1979 laa's~ sale at whicR~ Sohio and the native corporation~ obtained.. ' tract 76, The lower court affirmed the validity of tke sate and · · . -... . ~t:lm c~-~e is now on appeal before the Alaska Supzeme Cour'¢, A . deci~..lon is expected . . ..; Four other wells dz'itiad by Sohio in the vic. inJ.~y of the Sag · . ..~ .".. River Delta and noC'un~il txow'relea~ed publicly~ gave ttxe following - ,· . . . ........... .- ............... . ........... , . . ... ....... .... /~ ~,z~~''*'~'' ' ~.,2.A~ ~Sas suspend4d on l~rch 28, 1977 at a total / ' '~ { drilled d, epth of 12,564 ~' A b['ief drill '] ..' · .. ;.... .. approximately one hours_'s duration over the in'corral '.:'~, 12,222 Co 12,294 fo, in the Sag River Sandstone [>rod~ced . . ~ ; ,~. - .. --i 42,7° gcavity oi1 at a rate of 674 barrels of oil and a , ~ .. , gas oil ratio of ,Sag Delta ~2 was suspended at a total depth of 12,5.%5 · -on April 26~ 1977, Although the interval equivalent: to · ,the Sag Delta i~-I discovery zone was presen~ and gave oil · · · '..., and gas indicat:lons~ d~-ill'ste, m tests over the intez-val ..produced only water. Sohio has previously announced in a }fay 1975 p~-ess release that tim Sag Delta ()l p~:oduced oil from ghe Li$burnc foL~.at£°n at an tn£tial rate of 9~380 t~arrels-per day bug that the flow rage declined rapidly th~-ougt~out the test period, .i 0 0 o 0 · · Z- C . /,,'9-,00 .~~.. ' + ' I ~IA!~ I~ 2A D. S.T. ~1 PROGP~M 3. Set RTTS at 12,180'~ (tail 10' to 15' above top perf). 4. Rig up surface equipment, test head to 5000 psi. ~ 5. DST as follows: a. 5 minute initial flow b. 60 minute initial shut in c. Flow until cushion surfaces d. 'Sh~t in as directed NOTE: Monitor annulus during testing. 6. Reverse drillpipe to mud through DCIP, to tank. Equalize pressure, release packer . 7. RIH with DCIP below perforations and circulate dril!pipe clear. 8. POH - suspend or continue testing as directed. ~ JFV :j l e }&~rch 22, 1977 d~ l ,o O o.'--I Z l-.~.., ooo NIAKUK 2A D.S.T. #i PROGRA>[ Statu.: Cas ing: Mud: 9-5/8" Window 7" Cemented at Top TIW-PBR at Clean fk~t To 10.3 ppg in hole 8,830' 12,564' 8,297' 12,482'~ · ves: Drill stem test the interval 12,222-l_- to 12~ 294'/: to evaluate possible tubing comp].etion. Observe all DST safety rUles as per BOP manual. : _P,r o_j~r am: 1. Rig up test tank. Perforate 12,222/12,242' and !2,265.'/12,294'. ~ 2. Make up DST tools as follows: Temperature Gauge Carrier (200oF) 2 BT Pressure Gauge Carriers (0-6000 psi) 20' Perforated Tail 7" RTTS VR Safety Joint Jars (Howco) -~ydrospring Tester ~--BT Pressure Gauge Carrier (0-6000 psi) 30' - 4-3/4" DC DCIP Valve with Reversing Ports ~'--" ' '- ~-/4" Reversing Sub 3-1/2" H~DP and 3-!/2" DP to 200'+--above 7" top 4-1/2" DP to Surface NOTES: 1. Run 48 hour clocks - check operation. 2. Install lower Kelly cock on top of dri!lpipe (under Howco valve). 3. Cushion: Require 2500 psi less than a 9.6 ppg mud column at 12,250' ~ (9900' ~D), by using 50-50 methanol-water mix (0.93]_ SP. GR., 7.77 ppg) for the cushion. Use 8300~ cushion (6000'~ vertical depth). 2 ."-"SS-t, b 'l/o t o /- z,/.272' / .3 Yz " ,0,A~ 7oe'7' zvv~ .". ,,0/~ T~,, ['Tom Cook, Direc'tor OIL AND ("-~c <~q~,:,,~:. p ,. ~,-~o ~,.,',~rd ION CONi.iISSION ~,~ "~"~ ..... e 1979 ' ' ~uv ~mber 2, Divisi. on r4inerals & Energy [~anagement Hoyle H. Hamilto~//l~'~'~Z/~f~/'[/ Chairman/Commiss one Release o.f Confidential Well Data to .... ~' At the request et Bob LeResche copies cf the following confidential well data are being r~;leased to you. ~ Sa..g ..Delta ~2 Scale Interval " 2" & - . .... 2" & 5" Sonic 120 - 2708 2709 - 8516 9080 - 10750 10740 - 12500 '" 2" & 5" 2" & 5" "' 2" .. 120 - 2708 2709 - 9082 9080 - 10750 9082 - 1.0750 10741 - 12513 Mud Log ~:'2" -/-" 150 - 12535 Completion Report -- '~ pages (plus 1 page test summary) W'eli History ..... 1 page Core Description' -- ~'"~ pages (1 fu]l core and 1 sidewall) .,,, / Sag Delta #2A .. DIL ~'/~ S On ic CN- FD Mud Log Completion Report Well History Directional Survey '~" 2" 7864- -- 9346 ' 9539 -- 9742 :" "2 II 2" 7862 '-- 9349 9535 -- 9741 9535 -- 9745 7870 -- '9750 .. 2 page s 2 page s '9 pages (g!.':-oscopic) · Sa,::; Delta ~4 Sc al ,?; t n t e r v a 1 2514 -- 10960 10980 -- 12820 Sonic 2" '" ' 2" ' '.1 , ' 2505 -- 10965 10766 -- 12804 10967 -- 12811 i !,Iud Log 2" 2570 -- 12855 Completion Report -- ~ pages '? 7' Well History -- 2 pages .(plus 13 pages of test summary) Core Descriptions -- 1 page .;'~ .-. Directional Survey -,/i2 pages (gyroscopic multishot) --:,~,. ' ' '~. '. ' 5 / . Sag Delta ~".3 £, t,,.~. ! I. ~' 2" ' ' 104 -- 2451' 2"" I ~ 24'48 -- 8714 "~2" --1 9246 -- 11258 Sonic ,- /,, ;-2" & 5"/ 104 -- 2452 t'7 "2" 2.450 -- 9240 · .;.::~ .2., 924'6 -- 11258 FD ~'" 5" -- I~} 9246 -- 11263 . Mud Log 2" ...... "'~ 80 -- 11'279 {! - Completion Report -- 2 pages (plus 1 page stratigraphic summary) -, "> Well History -- 1 page ,' ~,. z ,. Core Descriptions -- 4 pages (3 sidewall and 1 full core) 8800 -- 12549 Son ic /2" ,' '~ 8800 -'- 12508 , CN/FD : 5" '~', 11090 -- 12563 l'!~]d Log V'2" ; '~-' 10025 --- 10821 '2" ' "] 8820 -- 12564 Completion Report -- 3 pages--'2, i' Well Iiistory -- ";1 page -.? D.irectiona'l ,.Survey-- ~,.""12 pag. es (multishot) D a t a Scale Inte 13val Niakuk !~3 Sonic ' 115 -- 2644 2'634 -- 10309. 10322 -- 13583 115 -- 2644 2635 -- 10314 10322 -- 13550 FD Hud 'Log ""2" . '7 .]/ Completion Report -- "2,,pages Well History -- ~, page Core Description 2636 -- 10312 10322 .... 13447 141 -- 13695 -- ,i0 .pages (sidewall cores) /, ..'..'-, ' zt:m lzsh.d mn this memo iv'ed ....a 'Si~"g'Te-copy""of"each ," ",--.' ', ' , e ? . HHII: be ,,- / Jerry Kreitner Date \ SOHIO PETROLEUM COMPANY Division of .Sohio Natural Resources Company SOHIO-BP ALASKA PRODUCTION DIVISION M~rch 14, 1979 3111 "C"STREET ANCHORAGE, ALASKA TELEPHONE (907) 265-00C MAIL: POUCH 6.612 ANCHORAGE, ALASI<A 99g02- Mr. Hoyle Hamilton, Chai~Tmm~ Alaska Oil & Gas Conservation Con, mission 3001 Porcupine Drive Anchorage, Alaska 99501 · Re: Sohio Petroleum cOmPany Sag Delta ~3 Well, Lease ADL-34634, Niakuk #2A Well, Lease ADL-34625, Sag Delta #2 Well, Lease ADL-28337, sag Delta #2A Well, Lease ADL-28337 Dear Comnissioner Hamilton: Information from the referenced wells was fiied by Sohio Petrole~n Company with theAlaska Oil and Gas Conservation Con, tree pursuant to AS 31.'05.035 and the regulations adopted ~ereunder. This infornmtion is due for release on the datesindicatedbelow unless determinations are made in acoordancewith th~ newly amended. AS 31.05.035(c), which became effective January 1, 1979. Sag Delta #2 Sag Delta #2A 4-22-79 4-29-79 5-26-79 1-26-80 You will recall that St~paragraph (c) of AS 31.05.035 was ~m']ded by means of House Bill 815 in the last session of ~he Alaska Legislat%m-e to provide that "...if the Commissioner finds that the required reports and information contain significant information rela'ting to the valuation of tmleased l~:d in the same vicinity, he shall keep the reports ~:d information confidential for a reasonable time after the disposition of all affected unleased land, m~less the o~er of ~e well gives w:it'Lc~ permission to release the reports and information at an earlier date". Please consider this letter robe a request for such a finding with respect to the referenced wells. This requesh is based upon the infozTn~tion -2- on file with the Comnission, relating to the referenced wells, ~d upon the information stated below which' indicates that each of the referencc~t wells is located on a lease which is adjacent to or near unleased State acreage, and that the tests perforned in such wells, the reports of which are on file with the Commission, would logically provide info~mtion relevant to. an evaluation of the unleased acreage adjacent to or near the leases concerned. We also note that there is an apparent typographical error in the wording of the amendnent to Subsection (c) of AS 31.05.035 which m~es reference to a finding by "the Comnissioner". It is our assumption tl~a~ tine legislature intended that, after January 1, 1979 tt~e responsibili'hy for making the determination would rest with the Alaska Oil & Gas Conservation Conmission, and not the Co~missioner of the Departn~t of Natural Resources. You will recall that the legislation creating tJ~e Alaska Oil & Gas Conservation Commission was adopted by the legislatum~e by means of House Bill 830, and the legislation am~nd~g AS 3]_.05. 035 was brought a]~aut by separate legislation in House Bill 815. ~ile the wording of ~ese t~o separate pieces of legislation was not reconciled, we feel ~at ti~e overall, intent of House Bill 830 was to transfer all functions previously exercised by the Comnissioner, Departnent of Natural Resources to the Alaska Oil & Gas Conservation Commission. If we are in error, h~ever, we would request you to forward this letter to the Commissioner, Depart- ment of Natural Resources, for appropriate action. With respect to the merits of the request itself, the .following infomnation as required by law, 'was submitted with respect to each of the referenced wells: 1. Sag Delta #2 - ADL-28337 i".. t h- Date given to DOGC 6-6-77 .. It~n 12 boxes of core chips 11 boxes of cuttings 4-22-77 Form P-7 Completion Report and well his'to,if Stm-atigraphic sunmary Core description SWC descriptions Mud log Electric logs: DIL/SP, BHCS/GR, P/ L, em/FDC, F L, GU, 2. Sag Delta #2A - ADL-28337 Dabe_ given to DOGC I'C~n 1-27-78 Form P-7 Completion Report and well history Casing record Directional Survey Mud Log Elechric logs: Dipneter, BHCS, DIL, 4 boxes of cuttings -3- 1-27-78 Application to drill, monthly reports, Sundry notices 2-9-78 DST data 3. Sag Delta #3 - ADL-34634 Date given to DOGC 6-6-77 2 boxes of core ct~ps 11 cuttings 4-22-77 P-7 coupletion report Well history Stratigraphic sum~ry Core descriptions SgI] descriptions Mud log Electric logs: DIL/SP, BHCS/GR, BGL, FDC/CNL, FDL/GG, HITf, PL/ML. 4-2-76 Statement of First Discovery * 6-8-77 Sunnmz~ of test options *This item is held confidential under the provisions of AS 38.05.035(a)(9)(c). 4. Niakuk 2A -ADL-34625 Date given to DCCK] It~n 5-23-77 Subsurface directional ~ ~ ',. '.'~i,'.r.) ....... 1..) t,.'. 6-6-77 t0 boxes of cuttings Application to drill It is our opinion that the logs and other well records are of excel, l~t quality in each of the wells and are fully capable of beh~g utilized by persons having knowledge of presently published data to make significantly more accurate evaluations' of the geology of unleased acreage lying adjacent to or near the references leases. It is our position that such a finding is all that is necessary for the Commission to exercise the authority required by AS 31.05.035 (c). If, however, you wish to examine tills question more fully, we are prepared 'to do so and can d~onstrate how this information can be utilized to evaluate unleased acreage adjacent to the referenced leases. -4- Further, we feel it is in the state's interest to delay release of ~is information until a lease sale has been held, as is presently scheduled for December of 1979. · Regardless of whether the infornmtion imdicates the presence or absence of hydrocarbons, public knowledge of it can only lead to a loss of the speculative value to the State of the lands in question. We feel this was the intent of the legislature in adopting the amen~~ to AS 38.05. 035 (c). ver~ ,t~A' y yours, John A. Re~er S~or At~mey blm A. ASKA OIL & GAS CONSERVAS'_. COMMISSION Robert E. LeResche Commissioner Dept. Natural Resources March 14, 1979 Hoyle H. Hamilton~ Chairman Sohio's Request for Extension of Confidential Period. I am forwarding to you the letter I received from Sohio requesting an extension of the confidential period for four of their wells. You will note that the 24 month confidential period will end in the next two months for three of these wells. Please notify us if you do extend the confidential period for these wells. cc~ Tom Cook · BP ALASKA EXPLORATION INC. P. O. BOX 4-13'79 3111 "C°' STREET ANCHORAGE, ALASKA 99509 TELEPHONE (907) 278-2611 TO: STATE DIVISION OIL AND GAS CONSERVATION 3001 Porcupine Drive Amchorage, Alaska 99504 ATTENTION: Mr. ~omas R, Marshall DATE: June 6, 1977 YOUR REF: OUR REF: SENT VIA: We are sending the following material to you this date. Please acknowledge receipt by signing and returning the second copy of this letter. SAG.DELTA #2 (10-11-16) core Chips '12 boxes Cuttings 16 boxes Core Chip~ 2 boxes Cuttings 11 bpxes Alaaka lpb DATE ~J" //~/ f/ 19 BP ALASKA EXPLORATION INC. P. O. BOX 4-1379 3111 "C" STREET ANCHORAGE, ALASKA 99509 TELEPHONE (907) 278-2611 TO: Harry W. Kugler State of Alaska Division Oil & Gas Conservation 3001 Porcupine Drive Anchorage Alaska 99504 DATE: May 23, 1977 YOUR REF: OUR REF: SENT VIA: ATTENTION: We are sending the following material to you this date. Please acknowledge receipt by signing andreturningthesecondcopyofthisletter. NIAKUKNo. 2A SUBSURFACE DIRECTIONAL SURVEY 2 copies 3/35/77 Roger C. ~errera~.......~--'-'~ Exploration R~p~sentative lpb RECEIVED DATE CONFIDENTIAL State of Alaska Department of Natural Resources Division of Oil and Gas Conservation 3001 Porcupine Drive Anchorage, Alaska 99504 MAILING ADDRESS: P.O. BOX 4-1379 ANCHORAGE, ALASKA 99509 Attention: Mr. Hoyle H. Hamilton Director Gentlemen: BP Well Number Niakuk #2A (23-12-15) Enclosed please find in duplicate Form P-7, Well Completion or Recompletion Report and Log, for the above described well. Also enclosed are: 1. Well History 2. Mud Log (Borst & Giddens) 8820-12,564 ft. - sepia and print " 1st attempt sidetrack hole-abandoned at 10,821 ft. 3. Electric logs, one each, sepia and print. Log Run # Interval Scale DIL iA lB BHCS iA Dipmeter iA FDC/CNL/GR/CAL iA 12514 - 8800 ft. 12549 - 12100 ft. 12508 - 8800 ft. 12545 - 8829 ft. 2" & 5" (iA & lB 2" on sa'~ne film and iA & lB 5" on same film) 2" & 5" 5~, 12563 - 11090 ft. 5" Please sign in the space provided below to confirm receipt. Enclosures cc: Niakuk #2A Well File #17 Very truly yours, BP ALASKA INC. Manager Operations ATE OF ALASKA SUBMIT IN I; OIL AND GAS CONSERVATION COMMITTEE i iiii i ii · i W£LL COMPL£TION (DB RECOMF'LETION R£P©RT AND LOG* ii la. TYPE OF WI~LL: Oil,w~:nL [] OASwEuL ~__J DRY [] Other Wildcat b. TYPE OF COMPLE~ON: ~w ~ WOrK ~ ~:~- ~ ~.~ ~ m~, ~ Suspension ~V FI, I, OVER EN BACK RESVR. Other NAME OF OPERATOR BP Alaska Inc. ,'~,ADDRESS OF OPERATOR P. 0. Box 4-1379, Anchorage, Alaska 99509 4, CONFIDENTIAL 5. AP1 NUM. F~LICAL CODE 50-029-20180-01 6. LEASE DESIGNATION ~ND SERIAL NO. ADL-34630 Surface ADL-34625 Bottom Hole 7. iF IND1A2q, ALLOTTEE Ct{ Ti{IBE NA~IE 8.UNIT,FAILM OR LEASE NAME 9.WELL NO. Niakuk #2A (23-12-15) 10. FIELD A.ND POOL, O1{ WILDCA. T Wildcat 11. SEC., T., ti., 1~7.. (BOTTOM }{OI~ ODd EC~rlVE) LOC^TION OF WELL (Report location clearly and in accordance with any State requirements)* At surface 1726' NSL, 1130' WEL, Sec. 26, T12N, R15E, UPM At top -~-c~l--l~t~r-~Lr~t;u~t~d-~al~v Sa~ ~ver Sandstone q 2289' NSL, 479' WEL, Sec7 ~.~ T12N, R15E, UPM. ~ ' .~:'~'¢ At total dep~ 2457' NSL, 362' WEL, Sec. 23, T12N, R15E, UPM Sec. 23, T12N, R15E, UPbl 12. PEI~IIT NO. 76-79 13. DA. TE SPUDDKD il4. DATE T.D; REACHED [15. DAzTE COMP SUSP OR ABAN-D.1--3--77 3--17--77 3--30--77 18, TOTAL DEPTH, MD & TVD[19, PLUG, BACK I'~ID & TVD~20. IF MULT~LE CO~L., ! 21. 12564'~/10150'TV~-- 8204'MD/7106'TVD'1 aow~Y. ~, PRODUCING !N~RVAL(S), OF ~IS CO.MP~TIO~--TO,P, BOSOM, NAME (MD AND None t16.¢.I.EVATIONS iDF, ]IKL3, ItT, EI?C)* ~17. GR, ELEV, CASiNGttEAD KBE=27.98' AMSL ]BFE= 5.09' AMSL INTERVAL8 I)[{[LI,ED BY CABI,E TOOJ .~ 23. x, VAS DIRECTIONAL SURVEY MADE Yes 24. TYPE ELECTRIC AND OTHF_~ LOGS RUN DIL, BHCS, Continuous Dipmeter, FDC/CNL/GR/CAL, CBL/VDL/GR/CCL, Mud Log L m Il , CASING RECORD (Report all strings set in well) CASIggC; S1ZE I WEIGHT LB/FT.~ GRADE I DEPTH SET (1VLD) See at tach[d 'Cas'i~g 'R]cordI' LINE~ iq[EC OITD HOLE SIZE CI~31LNTING REC-~' O t Iff2 i A?. 'IOUNT PULLED ii i i ~'. PEP~FO~AT'iONS C~ TO P OD C (interval size and nur~ber) 29. ACID, Si:CT, I;';{A'.;'i Gl{E, CE,lENT SQU£i:gZ" E'FC DATE F~RSI' PI~ODUCTION [ P~ODUCT~ON MEi:~I~ (~owi~g, !:,,as lifL pumping~size and type of pump~ IV, ELI., ',;TATUS ~Produmng or I I .- 1.vCO. - I FLOXV, TUBIN(} / CAS0}G PRESSURE IOXLO~T~ OI~BBL. 31. DISPOSITION OF GAS (Sofa, used ~or fuel, yen'ted, etc.) "'uil 0~ D;~ [TEST W vr~'rSS~D' n~ t ~eli flistory, Hud Log, ElecErlc logs, Hui¢lshot Survey .--. 33. , herebYsIGNED certify_~ that t,~r,oing T ayi~r~,~and attached informationTITLEiS completeManagerand correCt0perations ~ aet~r.,l.,u from all-avai] ableDATE rec. rds/,~_~ ' *(See Instructions and Spaces ~or Additional Data on Reverse Side) INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item: 16: Indicate which elevation is used as reference (where not otherwise shown) for depth measure- merits given in cther spaces on this form and in any attachments. Items 20, and 22:: If this well is completed for separate prcduction from more than one ~nterval zone (multiplecompletion),' ' so state ~n item 20, and in item 22 show the prcJucin9 interval, or imervals, top(s), bottom(s) and name (s) (if any) for only the interv,~l reported in item 30 Submit a separate report (page) on this form, adequately identified, for each additional interval to be seperately produced, show- ing the additional data pertinent to such interval. Item26: "Sacks Cement": Attached supplemental records for this well should show the details of any mul- tiple stage cementing anti the location of the cementing tool. Item 28: Submit a separate completion report on this form for each interval to be separately produc~l. (See instruction for items 20 and 22 above). 3,t. SUMMARY OF IPO~ATION TESTS INCLUDING INTER. VAI. TESTED. PHF, SS'URE DATA AND '~,.Y.,COVERIES ()F OIL. GAS. 35. G E~OLOG IC MARK[RS WATER, AND MUD ~ased Hole DST. 12222-12242 ft. BKB & 12264-12294 ft. BKB MEAS. IPH=5350 psig at 12168 f~ BKB '" BKB Sub-Sea IFP=2816 psig " ISIP=4775 psig " Lower Cretaceous 10812' 8913' FFP=3489 psig " FSIP=4765 psig " Kuparuk 11114 ' 9103 ' BHT=200OF at 12209 ft. BKB Kingak 11300 ' 9216 ' Flowed cushion ~o surface after 48 minutes(volume of air above cushion was 307 ft3). Recovered oil of 42.7°API Sag River Sandstcne12220' 9844 : ~. Shublik 12304 ' 9910' " 3B.'COR.E DATA, Aq~i'ACII'I3RI'Ei~ DI~S~'I~g.'I'/~O:N'$ 01~ LITI~IOLOGY, PO.YIO$I:TY, FRACTURES, APPA.R.EiW~ ~N~, ~.m;~c~m~ s+,ows or o,~. ~'~s o. w'~q~.. Ivishak 12393 ' 99 82 ' T.D. 12564' 10120' None 'C'O N'F I D E N T I A L W E L L H I S T O'R Y Niakuk ~2A (23-12-15) J an ua_~ff.,'.' 197__7_. Started operations at 1200 hours, January 3, 1977. Drilled out bridge plug at 2100'. Ran 54 joints 9-4/8" 47~ controlled yield N-80 Buttress casing and tied back from PBR at 2108' to surface. Arctic Packed 13-3/8" x 9-5/8~' annulus through F.O. at 2064' Milled window in 9-5/8" casing at 10,020' to 10,075'. Laid kickoff plug ('{40 cu. ft. Class G). Cleaned out cement 9820' to 10~025'. Stuck pipe 60' up into 9-5/8" casing. Pulled loose. Dynadrilled to 10,079'. Ran drilling assembly to clean out. Stuck pipe 60' up into casing. Backed off. Fished -pulled loose -drilled 8-1/2" hole to 10,14Z~'. Febru_a_r~ Drilled 8-1/2" hole to 10821'. Could not get away from old hole. Set EZ-drill plug at 9895' and pumped 174 cu. ft. "G" cement through EZ-drill plug. Perforated 8-1/2" holes at 8950', set EZ-drill plug at 8913' and squeezed with 348 cu. ft. Class "G" cement. Ran and oriented Eastman permanent ~ipstock at 8915'. Milled window 8891' to 8900'. Lost window. Milled section in 9-5/8" casing from 8830' to 8868'. Ran under-reamer 8830' - 8861' . Placed 130 cu. ft. cement kickoff plug through drill pipe at 8868'. Ran Dynadrill and sidetracked through window. Drilled 8-1/2" hole to 9025'. March~ 1977 Drilled 8-1/2" hole to 12,564'. Ran wireline logs. Ran 110 joints 7" 29# N-80 Buttress casing to 12,564' and hung as a liner at 8297'. Cemented with 2156 cu. ft. Class "G". Inflow tested lap - okay. Perforated and drill stem tested 12,222'/12,294'. Installed 7" EZ-drill bridge plug at 12,170' and capped with 57.5 cu. ft. c~ment. Ran 9-5/8" bridge plug to 8204'. Laid down drilipipe, displaced top 2000' to diesel. Installed wellhead cap. Released rig at 1800 hours,~March 30, 1977. BP WELL NIAKUK #2-A (23-12-15) CASING RECORD CONFIDENTIAL CASING SIZE WEIGHT LB./FT. GRADE * 20" 94# H-40 * 13-3/8" 72# N-80 * 9-5/8" 47# N-80/Soo 95 9-5/8" 47# N-80 7" 29# N-80 DEPTH SET(M.D.) HOLE SIZE CEMENTING RECORD 78' 26" 80 cu. ft. 2714' 18-1/2" 3906 cu. ft. 10,997-2108' 12-1/4" 3050 cu. ft. 2119' Tied back to existing 9-5/8" 12,564-8297' 8-1/2" 2156 cu. ft AMOUNT PULLED *Already cemented in Niakuk #2. CONFID~EN'I"I/~[ STATE 01:: ALASKA COPY B. Po Alaska COMPANY Niakuk 2A Prudhoe WELL NAME LOCATION JOB NUMBER A377 S0308 SURVEY BY Micl~ey Pollard TYPE OF SURVEY Multi-shot ( DATE , \ 3-25-77 Alaska COMPLETION REPORT MARCH 24' 1977 ALASKA INC. NiAKUK 2A N~AGYETiC MULTI-SHOT SURVEY KB ELEV, 30 FT, RADIUS OF CURVATURE,,METHOD OF COMPUTATIONS COMPUTED FOR EASTHAN WHIPSTOCK INC. BY F~ M. LINDSEY AND ASSOCIATES RECORD OF -S-0PJg-EY ALL--C~T-EI]E-A-TI"gSS--'~ER-FOR"ME-5--B-?--I B M EUE-~TRON ! C COMPUTER ~,.~A~E ~ ~n AC}/^ COPY ........ V{' TRUE OOG LEG "'~= DRIFT VE ,.~.AS. RTICAL SUB DRIFT TOTAL COORDINATES C L 0 $ U R E S SEVERITY b ...... ¥~ 5"£'G. DISTANCE ANGLE DEG/!OOFT DISTANCE b M S -CL~'WIT:k-UK--2--LF~'~zJS-0TqE'D--gE~TI-C'~;L--TU--2 ? 5 6 . --2T5-5 .... g"ib ..... ~'?-5'5700---2-'?"2-(5-70-0 .... N"~IT05E 2850 4 0 28a9.91 2819,9! N i,OOE-- 3.37 N 0.00 W 0.00 S O 0 0 W 0,0OO 1.29 E 3.61 N 20 59 59 E 3,729 3,51 -~.-'g'-~;$ ........ ?-zF5 '-2-~'274-F0" 2-'9'i21,-~o Nt 9.00W lz. 7'2 N --~3~-5----~-0 ..... 9---~5'~d-;'2-~-'~ 004-;'-2 ~ ...... ;'~ !-9 ;'05ff ...... 2"~'-'"'29 ' ~,{~ --9i'29 ..... i2-'~-~-r2 5';'5'7---3'o~ 5-;'-57 ..... N 1-9 ;' O-O"W-- 4 3. o ? N~ --"~2~-'-~-3--'-~"k-----~217~20----~L87'tJ20- ,-- - .- -.. ..... ;q-2'a-"'~OW..,, 62.55 N --~'3-'1'5-'I5 ..... i~----~3~7;-2~"277';-2-~ ..... R~ 9~-'O-OW 84.20 N --~'59-7 ' 23 ..... ~ ........ 257~ d ...... . - .0 ,8 354'i','O ~- ..... ~ql 5 ~'Oow i73.99 -~'~'~'N'i-:~ BO' ...... 3 6 ~ 7-i 1'0 3'62'/ ......~ ~ ....... ,.,_~, ~5' · o'o':~-l-ro-;-'l"~. , --'~ 7 S~-'2 T --~5 ...... 3 T4-~-"~9 37i ['"49 .... ~ La,0'0W 250.23 ,:.-fi, ....~ , ~ .... 4~, - Y-'~5 3°~3,11 ~95'3'~! 1 --~! 3'OOW 387'~ 9-i 0,18 W 4,85 W i0 18.30 W 26.83 W 34~98 W N a. 3.59 W 53.00 W-- N 62.69 W N 73.05 w N 83.58 W N 94.35 W · 87 W · 72 V, ~ $~: 15- dO~,-2-~--gB----4'032'Y~B---N'i?+-~OOW 436.~a N !16 ~:-5i-'23 0 4: ~-:.: 5 ~ l' iii: 5 .... :' :"-:',' o 0'::J :: ,;'~-5 · z ~ ,,: : z 7 4431~ ..... 3~ 0 a296,86 a266,86 --R'-'~'-00W-- ........................... 4532 35 0 4.374,33 aSaa.33 N1A~5'~W ~g'2 5 ..... 3 5 ..... b---l~5-O Y5"i--~4'20"' 5: ..... N ~. OOW 587.26 N 145.70 W 639.77 N 154,~9 W 12.72 26,73 N i0 27 54 W 2,419 44~36 N 13 52 5 W 2,151 65.!7 N 16 18 48 W !~886 88.38 N 17 40 39 W 1.655 11~S~'6--'N'-':-i .... ~"8 9 W 30207 :46.68 N :7 z? .... .............................. 260.68 N 16 16 30 W 3.465 305.72 N 15 51 58 W 2e702 N 0 50 9 W 4.051 12.60 ~i,37 8'-0';'13 .... lOgo 75- Z00.~3 238,9~ .... 281,1i-- ......... 326.03 451,72 N 14 59 40 W 0,612 ..... 553.39 N 14 20 56 W 0,863 5i4.43 6OSoeS N --658'.16 N 13 30 32 W 1,120 615.C5 692,38 N 163.29 W 7!1,37 N 13 !6 i3 W O,Ai7 666.i0 ALL CALCULATIONS PERFORMED BY I B H ELECTRONIC COY, PUTER TRUE MEAS, DRIFT V~-- . ~.RTICAL SUB "~--E'~T!~ ANGLE--'~'E~-TH SEA DIREC DISTANCE DOG LEG DRIFT TOTAL COORDINATES C L 0 $ U R E S SEVERITY SECTION _.;:. ..... :._': .... 7_ ....... 499~ .... ~8--i-5---'~'/Z~9;'04 4719-;04 N 8.00W 914.87 N ........................... 198.00 W 936.05 N 12 ~_9_.~ .... 3~__.!.,~__._~.~2_~_8~_~..792,8.5 ...... .N.~O.,O~.~ ........?.72_~34 N _~_~_~_!.0_.2~___~..1~ ~ .... 12 ......... ! ..... 27__~f~: .... ~ ~.3 I.~ ........... 93_8,26__ 5136 38 15 a895~89 4865~89 .N 9.00W I029~13 N 2i6.6i W 1051~68 N 11 53 10 W 0.666 993.38 --5280 39 1'5 ....... Z~'959,~20-' ~939"20 ...... N'9.00'~ i~7~'24--~ ........ -~J~-~'-~l W 11i0'44 .... ................. 5373 40 0 5040.83 5010.83 N 8.00W 1145.90 N 234.58 W 1169.66 N, 11 34 9 W 0.92i -~'g7-40 ......... 5---'~ i 12; g"~- ..... ~'0'82; 84 ..... N~''~ ,00'~V ....... i'a 0 ~'. 86-"W ......... 2 ~-~ ;~"g'""~,~ ..... i7 29, ~'4-';~"-"i'i Z~ i ~-~"-~ ....... ~ i5 ...... ~ ~ 83', 4'2 ...... 5i ~ ~, 42 ........ N ...... 7 ~'o O~~ ....... 'i'255,9~'-'-~-----2g-'9~' ~g-~----i'-2 S 6'; ~'2 ....... ~'--i-1 ......... 9 .... 5~ ....... ~'9'g~--~'9-'--O---5-~"8'9~';-~'~---5~5-9"',-~'9---N--5-;'OO%---i'5"~"2";"7'~ N 270";~5~~'~'5g';-~'i-~ ....... g-5-~--~-4--W 6 4 ~'~'--'~'~' ..... -0---'5 ~ ~'g-;' 75---5-'~0 'g ;'~5 ..... N--?-;'50'E---i'~-g'4-;"O'i-~- ~-'~'4-;-~-g~ f-~'5'-S'L'8'g--N---?-ig .... ~ 9 w o · --'6'5'2'8 ....... ~-~--~'0---59"0~'7~'6~5'873"';'2E---R--'8700-E---I'9"O'8';-~ N 2'2'-5";-55' W --!92-'i';"~'0"'"~ .... 6--~'4 ...... 2'7 W -- 0 --~-i-5 ~ 6 ~'-O~'5-V'2'O- ..... 5-UOS',-20--N ..... ~-;'-00E---203-9-;5 ~ N 207~;"i"i-~ -- 2-~5-¢; O'Z'~q ....... 5-%7 ...... ~ 4'-W 6902 46 30 ~-'~g5~'-20-~-~'5,20 N 8,50E 2172,70 N ~88~10 W 2180,82 N 4 56 ~3 W 0,855 6996 46 30 6229.91 6199.91 N 8.00E 2240.18 N 178.32 W 2247.26 N 4 33 4 W 0.38~ 2199,52 7089 46 45 6293.78 6263.78 N 8~OOE 2307.12 N 168.91 W 2313.29 N 4 11 14 W 0.269 2267~i! 7463 45 15 6550.92 6520.92 N 9.00E 2575~52 N 127.60 W 2578.68 N 2 50 10 W 0~388 25~8,59 RECORD OF SURVEY ALL CALCULATIONS PERFORMED BY I B Pi ELECTRONIC COkiPUTER TRUE ?EAS. DR!F~--~UE-~T-ICAL-- SUB ~'~TH ANGLE DEPTH--SEA DRIFT TOTAL COORDINATES C L 0 DIREC DISTANCE ANGLE DOG LEG SEVERITY SFCT[O~ DEG/iOOFT DISTANCE ~ H DEG. D H S 7557 45 15 66!6.52 6586.52 N 8,50E 264Zt07 N 117,36 W 2644.68 N 2 32 36 X t.097 26~ ~-' 6653.4i N 9.00E 2705.92 N 107.53 W 2708.05 N 2 15 32 W 2.700 2670.~8 672~.25 Fi 9.50E 2768,00 N 97,42 W 2769,71N 2 0 56 W 1~612 --?837 40 0 6823~85 6793,85 N 9,00E 2827,76 N 87.59 W- 2829.12 N 1 46 5'4 W 1~362 2793~85 --~'0~ , ...................................... ,,~i 40 ~ ....... ~895~'8~---6'865~86 ~,~ 9.00E 2887,44 N 78.23 W 2888.50 N 1 33 7 W 0,000 _. --S02g"'--~O. . ...... 0 ..... 6967,10 ..... 6937.10 ...... N '8.50E ...... 2946,52'"~ ........... %9*{g-'-~, ......... 29a7,33. .... N ........ . ...........811~ ............... 39 45 7~39~2.~ ..................... 7009~2.~'g ...................... N 8~OOE 3006,16 N 60~49 W 3006~77 N t 9 10 W 0.344 2974.26 --~2ii .....40 ....... 6--}'ii0";-6i 708-0"51 ...... ~"'~'~00E--~"05'5,'2~ ~ ....... ~'~'~i"~--~ --~'~0~-'4~ ...... ~ ...... ~iSZ-,'g2 ....... Pl~Z,SZ ......... ~ ~,~0[ ........ ~1'~;0~-~ ..... ~'~;-f~'-W---~i"'Z~',~ 8398 40 0 7253.86 7223.86 N 7.50E 3184,27 N e_5.d.Z~ ~____:~____~_l.8~'47 N 0 38 ~, "· lO N 8,00E :422.68 N ,..8 W 9782 47 30 8239.42 8209,42 N 8.50E 4143.79 N 85.25 E 4144.66 N I 10 43 E 0~612 412i~19 RECORD OF SURVEY ALL CALCULATIONS PERFORatED BY I B M ELECTRONIC CO~flPUTER .."',EAS, DRIFT vr:RTICAL,_ ....... SWB DRIFT TOTAL COORDINATES C L O S U R E S SEVFRIT¥_. , .~:- '-' "' ~ 'r "" ,'4.:.._,... ,. ..,. .< :, .... '- , . .', v,'" - F . - ,,'_!.5..i_A_.~'~ ?-_E_ Dr.__P'""H ~,,,..:u._ DEPTH SEA DIREC DISTANCE A,""!GL.E ........D_EG./.._'I._OOFT ""' -'~"- D ,~-! DEG, D ~ $ 10155 46 15 8494,26 8464,26 N!O,50E 4412,T0 N 128,43 E_~ '4___4_!~_,_5__7_._L~_~__1__.~.0____i E i034.0 45 0 g624,35 8594,35 NI4~OOE 4540,90 N ..~_5_~_7~_Tj.__& 4.5_z_+..3.~.6._~__~_!___%_5..~ ..... 2_I__E ........ .0_.,,.3.8_~_ ";~' _1_0J_35__46 .... .1_5 ..... 8590-.79 ..... 8660~.79 ..... ,.N'!4.,OOE ..... ~606.,~.1.9_.___N- .... 1.7__O:.,,_.!.~..._E_ ...... ff61..0, o08 ...... _.N_ ....... 2 ...... 9 ..... 5.3 E 1,3.16 45'91,72 105'>o 47 0 8755.34 8725.3~ N!4.OOE 46'73.08 ,N 190.67 E 4676~,97 N 2 20 11 E 0 ~'" ..... , · .~ ....... ~ ............................ 10713 49 0 8878.&5 88/+8~,Zi-5 NZ6.00E /'+80/'+*99 N- .226o64 E ~810.33 tN 2 42 2 E I.i30 ~"0905 50 ........ ~'5 .......... ..... 899~,12:--8969~'!2 ....... N!T"50E 4942,22 N 26~ ,3~ .... e 4940,=9 N 3 5 4 E 1~28.6 47.36,1~__ I~1275 53 0 92Bt,!0 9201.10 NiB~50E 5220,55 N-- 362~85 E 5233.:~ N 3 ~8 33 E 1.262 5224~4~ 11462 51 0 93a4~93 '9314~93 Nig~50E 5361~03 N 410,53 g 53'76.72 N 4 22 ~4 E 2.246 5369~83 __f ......... f.__?. ....... 2..:: ....... ~:. ............................ ? ...... 1_: ...... P.i ..... ~.'..'~ .................................1183847 O ~.5.~Y.,..~~ '~ ....... ~: ............. 95~..07~ ............... Y:'"',~27.SOE ............... >6~,~= ...... a 73 ,N ~20.21 .... g 56~8~74 N 5 17 g E ~>59 >6a:5~31., -::~'32----'~a- ....... 0 ~'S5-4-1'9'5---9'8~'~-';-9"5 ..... N'a'S', 5-0 E 5S"~'"~"'-~"9-:-~:--55' fi"g~E--~5) iO-;~'Y-7~-~:-'--:-2-~7-'E ............ :'"12 :': ........... :'~0 ~'~ o: ....... -i~'~ Z 7--"':: ..... :O ....... -~"~2:4' ;-'?i ..... ~'S 94""V: .......... :g: O' ~' ShE .... ~74'0'; O~--'N- ..... 5-S'3--;":~-'3-'"E ....... 5"?'~ ¢';'~"1: ...... ~' ........ ~ .... g~ ...... l'3 ...... E- ........ i '~Vi:": .... -5'V~ V ~ :5 .... ............. :'2~'i :'-:'-~ ..... 0~'-~'~'~-'%-~"5-- ~--S-':' 'i-'O-': ..... E'z 5';5 5E--YYfO-;:'E:<~%::'i"g'8' E --':':-75- ;3: i-'~-'S--':'5--':'6-E~~-; ~-'6 5--~- :"~'V ~ i 12'~9S~ ~ 36 ~=0 10013.61=~ 9o83. ~61 N34~0~. ~ ,~ 592°~68. N- 712.c<a~ . E 5972~31 N 6 51 0 E 0.91i .~972.14 -i-'P% ~'~ ~':4 ....... 0---%'0-0'~-7'-~--~ 0 "-]'TjO 5"7 '~'-8';~ ....... N~3~F~ ........ ;:0 .......... E 5.~-'~"7":.~.78 ......... ,;ii ....... 7 ~,.. ~ ~62;"5 ...... : ..... E~~"F"--; ..~2 O. ,~'-x'--FF~ ,~ .... :7 ....... :~ ...... i1~ ...... E:: ............. 0.60~'; ...... 2,~020 ~ 73 ..................... ~OTTO~ HOLE CLOSURE 6060.13 FEET AT N 7 16 47 E N/...~F.....4:_SURED DSPTH AND OTHER DATA FOR EVERY EVEN 100 FEET OF SUB SEA ,DEPTH, TRUE MEASURED VERTICAL SUB MD-TVD VERTiEAL __ DEPTH DEPTH SEA DIFFERENCE CORRECTION TOTAL COORDIN~T__E~ 2830 2830. 2800 0 0 2,16 N · 02 E --29]30 2930. 2900 0 0 1i,07 N 2.60 E 3032 3030. 3000 I i 25.58 ~is~. 3i3o. ~1oO ~ ~ 4:3.96 3236 3230. 3200 6 3 65,40 N 33~0 3330. 3300 9 3 90,24 N ~4~5 ~a~ ...... ~'in ..... u, ~ .~0 14 5 120,73 N 3~2 3~'e. '-3~00 2~ 7 157.z0 N 2660 3S30. 3600 30 9 198.26 N 4~6i 19.55 W 28,87 W 38,05 W . , 48,42 W 59.50 W 37.7 1 '3730; ............ :3700 ......... 4'1 11 38S 5 3o,, 3,.O'; .......... 3800 ........ 55 14 4002 3930. 3900 '71 16 4]]1g 4030'~ ....... 4000 ............... 89 18 -4-238 4130-; ..... ~1 O0 ..... i--07 18 A 3"57 ~-2"$-0 , --420'b' 127 20 4~78 4330, ~300 1~8 21 '~53' 0 · 45 O0 ........ '~'8'3 &,---'~'8' 0d ...... 5 O-3'b 7 ....... ~'00 O ....... 5 5'20-;5-50 5-6-¢0 · --5-6-00~--52 o 5? 3-0-;'-: ....... 570-d ¢5 6 -- 5~3'0. 58"~'0-' 595 6U"~"O"J---'EO-OU a6oo --4975- 5229 5'359 ,,, ",4, ~,.; ~ 5~22 5'75? 5 89-0' ~6'OIg 615 0 6'28~ 8'4 2' 5 656-5 '6-7~-7 6~51 22 25 28 27 27 33 35 33 29 36 39 4O 244~41 N 71,59 W 2 9'-8" 6 o"--.~ ........... 8 4 ' '4 8' w 356,19 N 97*92 W 478.20 N 126;'~'i W 1 tv~-5-;-5'5 N 220.79 W 't ~2t9.88 N 244,19 W 1:306,61 N 25g+084 W 1396,74 N 266~'55 W 148~,96 N 272,30 W 1565,57 N 267,12 W 42 2033~84 N 6130, 6i. 00 721 44 2136.23 N 6996 6230. 6200 766 45 2240,!8 N 207.9i W 178' ~ 2 W MEASURED D,_'PTH AND OTHER DATA FOR, EVERY EVEN 100 FEET. OF ,SUB SEA ~c_~r'"""'TH. TRUE MEASURED VERTICAL SUB MD-TVD VERTICAL DEPTH DEPTH SEA DIFFERENCE CORRECTION TO',',,. 7142 6330, 6300 812 46 2345,12 N 7287 6430, 6400 857 __7~76 6630, 6600 946 77!3 6730, 6700 983 7845 6830, 6800 1015 7975 6930, 6900 1045 8106 7030, 7000 %076 8236 7130. 7100 !!06 8367~ ................... 7230. ......... 7200 ...... I t2,7 8497 7330, 7300 t167 8628 74.30 ~ ......... ~4.00 ......1197 8759 7530~ 7500 1229 8..:~o 7630. 76oq___.i 2 ~o 9025 9165 9~12 9a65 9618 9768 9915 !Or~6! 10206 10348 IOa92 io~9 109a8 _ 773Q~ .... 7700 ..... ~295 7830, 7800 1334 7930~ 7900 !~81 8030. 8000 1435 8130, BlOO ia.88 82~ 8200 !5'38 8330~ 8300 !585 8a30, 8400 1631 8530, 8500 1676 863o. 86oo 17~7 8730o--870'0---i761 9030, 900~ .... T918 silo. '%f05 i'~Ts __ 92~0. 92'00 20z~.3 2449,54 N 43 2655~41 ~ ....... !.._~_46_._~~5 37 2747~71 a .l,.O0..~?.!.. W __32 __2832,._84 N 86~88 W 30 2915~39 N 73,93 W __31 2998,58 N 61.~82 ....... W 3O ~.1 .~0 30 32 3i O~t~i2.~.N .... 49~°6..W 316_4~44l_...~ ................... 38,48_W 3330.,7_E....%~ !.5.,41 ..... W 34i4~28 N 3~66 W 3498~39 N 8~g.1 ....~ 354~,3~ N _19~~ 5!¢5.!~67 N 30..~02 E 3792~78 N 40.16 E 3908,31 N 53,~2 E 35 39 54' 53 z+O 2.3__,__! 7 N 68.a0 5 50 ~.- !.33 ~_.63 N _83 °_.5 47 ~+240~ ~ 9 x ~nn 46__ 4345,63 N i_1 O, ~ .__.~ 45 a44._~ e.67 N .13.5,3 i 41 4546~39 N 159~08 44 4646,89 N 18&, i4 48 475'i'[61 N 2ii'43. 53 4862"~- 79 N 242.75 56 4977~ 5'7 N 277~a~ 6~ 5219,24 N 36i,74 iia35 9330, 9300 2108 65 5343,62 N 403.90 E 11595 9~0° 9400 2!65 57 5~'~.-~'b N 445,72 E __11897 9630, 9600 2267 47 5662,46 N 539,69 E 1203a 9730. 9700 2304 37 5744,08 N 585,77 E ;N~EASUR~D DE-PTH AND OTHER DATA FOR EVERY EVEN 100 FEET OF .SUB SEA D · ~- .~ TRUE MEASURED VERTICAL SUB MD-TVD VERTICAL DEPTH DEPTH SEA DIFFERENCE CORRECTION .12154 98B0, 9800 2334 30 ~814,42 N 630~75 E 12291 9930, 9900 2351 27 5878,2'8 N 675~75 E 12a16 10030, 10000 2385 25 5939~54 N 718,96 E 12540 I0130~ 10100 2410 24 5999~90 N 759~82 E TRUE · R T i C A L 5_W.-5____ S~ DEPTH A TOTAt 4000 3928~ ~898. 355~33 N ~7_.~_. g! 5000 4749. 4719, 915.48 N 198.09 W 6009 5514, 5484~ 1553~55 N 268¢_g7 W 7000 8000 6 z 3 2~.? .......... 6 2 o ?...; ..... _. .... 2..2~.a ,PZ._.!~____!...ZT.,..~_! w 6948~ 69i8,: ' 2931.29 N 7t~58 W 12000 9704. 967a. 3571,38 N 17,30 E 430t.65 N 109~31 E 5015.81 N 290.99 E VERTICAL SECTION 1200 CONF!D,C~!'r!AL . STATE OF ALASf(A COPY .!,..,~ ........................................... ~ ............... :.. ............. % ................................. L ...... ' i ALL DEPTHS SHOWN 1 -, · k - - ,- ARE TVD. - ~ 520ON '' i ....... ._; , ............... j ...... !~,.~ .......... . . TVD :10,150' TMr3: I? .fiG~i- SCALE ["= I000' B.P. ALASKA INC. NIAKUK 2A RADIUS OF CURVATURE MAGNETIC MULTI-SHOT HORIZONTAl_ VIEW ii SCALE I =1000' B. R ALASKA INC. NIAKUK 2A RADIUS OF CURVATURE MAGNETIC MULTI-SHOT · -~- ........... ' ~~ '" i-- ' ........... Tv' ~__ ~o, tso' ! ........... ~o,ooo TMD= 12,564- 9600 8800 8400 ................................... : ....................... ~'600- i 5600 · - 5200 · _ . .... ALL DEPTHS SHOWN ARE TVD. .......................... : ............ 4000' . ..... 3600 5200, ................................................................... 2800 . 'I GWE/6-22-B9 NI AKUK _WELLBORE DI A6, RAM ~ ~CTlC p^~X ~ CFJ'IENT 2000 FT DIESEL 10.4 PPG 't1UD 20'CONOUCTOR 9 5/8' 47mlFT N-BO 8TC CASING TIE-BACK g 5/8' CASING tlANGER WI PBR ~ KOP (DIR: NI.O'E MAX. ANGLE: / 9 5/8' EZ DRILL PACXER LINER TOP 9-5/8' 47m/FT N-80 BTC (WINDOW MILLED ON BOTTOI'I S10E OF 9-5/8' CASING IN NIAKUK ~"2 TO SIDETRACK NIAKUK ~'2A) KB Elev. - 27.98' AtlSL 78 FT 2 lOg FT 2714 FT 2800 FT 820,4 FT 8297 FT 8830 FT PBTD , 11894 FT CEI"IENT PLUG ~ ? C I 1894-12 ! 70 FT HOWCO 7*EZ DRILL PACKER 12 ! 70-12177 Fl' 7" 2g=IFT N-80 BUTT LINER PERFORATION DEPTil: ! 2222' ' 12294' 12564 FT PROPOSED DEVELOPPS~]T PLAN NIAKUK W~r,L (23A-12-15) BP ALASKA EXPLORATION INC. Page 1 of 11 1. SITE LOCATION (~ee attached Survey Plat) The proposed si~e of well Niakuk ~2A. (23-12-15) is the SE 1/4, Section 26, T12N, R15E Umiat Meridian. This surface location is identical to that of Niakuk ~2 exploratory test drilled in the 1975-76 winter season. 2. SITE DESCRIPTION The site on which the drilling pad has been constructed under permit letter dated April 9, 1974, is a small, unvegetated gravel island, in Prudho~ Bay, 1-1/2 mileS NW of Heald Point. ~ ground elevation is approximately 2 feet above mean sea level. ~Gravel was added to the island in 1974 and 1975 to construct the drilling pad used for the drilling of Niakuk #1, ~iA am~ Niakuk #2. The same pad will be used for the proposed well and no further addition of gravel is necessary. - The island is the furthest north of four which are arranged in a line trending NNW-SSE at the eastern edge of Prudhoe Bay. As the island is not large enough to acco~te the drilling camp and the rig, the camp is sited on a smaller island south of the drill site and next in line to it abOut 1300 feet away. 3. SITE DRAINAGE The drill site pad surface and ~Drk area is five feet above ground level and it slopes on all sides gently towards the sea except in the vicinity of the drilling rig itself where the ground surface slopes towards the well cellar. A reinforced plastic membrane will be placed beneath the entire drilling rig structure and its surface will slope into the cellar. Any oil or other contaminants which leak or is spilled from drilling rig equipment will drain into the cellar from which it can subsequently be pumped and transported ashore to a disposal reserve pit. Page 2 of 11 Facilities located on the.pad surface which might contaminate will ~be surrounded by berm~ of gravel and ice. 4. AREA WILDL/FE Previous field experience and observations have revealed little wild- life in the area during the anticipated operational period (December-March). Construction and drilling operations for the proposed well will con, hence ' after freeze-up and be completed prior to spring thaw. During· the past tw~ winters the o~y wildlife which has been seen near the location is Arctic fox and ravens. In the past, the drilling activity has not interfered with the daily habits of any wildlife at this location. The proposed program will continue to maintain that condition. 5. AREA FISH The sea surrounding the Niakuk island to be utilized as the drilling site is less than 5 feet deep and the route to be used for an access ice road to the shore will cross water depths of less than 3 feet. Consequently, winter ice will freeze to the sea bottom removing the possibility of affecting overwintering fish. As the Niakuk islands are naturally occurring features, the presence of the drilling pad will have no adverse effects on sun~r fish populations. 6. AREA ~~ No settlen~nts or villages are in the vicinity of the proposed location. The location is approximately 4.2 miles from the Arco East Dock and is considered effectively within the extensively developed Prudhoe Bay Field area, operated jointly by the ~applicant and Atlantic Richfield CoT~0any. At Deadhorse Airport, 10 miles to the SW' are located a hotel and public Page 3 of 11 airport suppor~ facilities, year round roads exist only part way between Deadhorse and wellsite. Surface transportation to the drill site is poSsible only in the winter after .construction of ice roads. 7. ACCESS ROADS The access road is. shown on Map sheet Beechey Pt. B3 SE, and Drawing #84D-B-2. Access to the drilling location will be from the Prudhoe Bay Field Spine Road System by way of the Arco East Dock and then by an ice ' road running offshore parallel to-the coastline before turning north to the Niak~k Islands. This ice road will be constructed on bottomfast ice and it will be approximately 4,2 miles in length. The road will be maintained and clearly rmtrked during operations. Construction equipment, fuel, all supplies and the drilling rig will be transported along the Spine Road and over the ice road from Prudhoe Bay by truck and rolligons. The rig .is presently stored at Parker Drilling Yard, 10 miles from the location. An ice road generally following channels of the Sagavanirktok River will give access to t~o water supply lakes 11.5 miles from the drilling location. Water for drilling camp use, well cementing and bOiler use will be taken from an approved location in the Sagavanirktok River, accessible over the improved spine road system and ice roads. 8. SITE PLAN (See Drawing #A75D-W-119) The drillsite has been constructed within the confines of the island, of ice-free gravel with sufficient area for the drilling rig. The camp is located on a gravel island approximately 1300' southeast of the drilling pad, as %r~s the case when drilling operations were conducted during the 1974-75 and 1975-76 drilling seasons. The attached Drawing #A75D-W-119 gives the location of all facilities at the drillsite. Page 4 of 11 9. GRAVEL SOURCE~ ' The gravel pad was constructed for the earlier wmlls using gravel from exposed bars in the Sagavanirktok River. The pad is in good condition and no further addition of gravel is required for the proposed drilling operation. 10. PERMAFROST The drilling pad has been constructed on an island. Total depth of permafrost beneath the wellsite is approximately 1500 feet. Facilities with a source of heat (i.e. camp) will have insulation and/or air circu- lation beneath· to insure that thawing below the gravel pad does not occur. The drilling rig is to be supported using v~oden piling previously in- . stalled. No additional piling will be rec~ red to support the rig when drilling Niakuk ~2A. - 11. RESERVE PIT The reserve pit at the drillsite is for emergency use only. All mud and drilling waste will be.. collected ar~ trucked to an existing disPOsal site at Sag Delta 33-12-16. This system worked successfully when drilling ., the previous Niakuk wells. An ice berm will be constructed on the sea ice to provide a secondary conta]rm%ent, for well bore fluids in case of an · eraergency. Any fluids entering this berm will be picked up and disposed of in our onshore disposal site. 12. FUEL STORAGE (See Drawing A75D-W-119) Fuel will be stored in steel tanks %~ich will be surrounded by a snow and ice berm constructed for secondary containment. Once -hhe snow bern is constructed it will be sprayed with water %~nich when frozen will form an ice barrier. Any fuel from a spill coming in contact with this berm 'v~uld be at ambient teaperatures. Inasmuch as the drilling program calls for Page 5 of 11 completion prio~ to.break-up, these dikes will be competent during the period of operations, based on past experience. The use of snow berms also eliminates the need for additional gravel and site restoration. Fuel ~flow diagrams and transfer procedures, valving sequence and safety precautions have been or will be developed for fuel facilities after installation, and will be available for ins~c~on and review. All personnel ~Drking in the fuel handling area will be thoroughly trained in these procedures to avoid . possible mishaps. 13 .~. ~ PREVENTION PROGRAM EQUIPMENT Upon rigging up before re-entering this well, blo~Dut prevention equipment (BOPE) consisting of three 13-5/8" 5000 psi W.P. Shaffer I~$S rams, a 13-5/8" 5000 psi W.P. Hydril annular preventer and a ~ choke - manifold will be installed. These preventers are powered by a 160 gal. Koomey accumulator system with both nitrogen and manual back-up. The POPE will be thoroughly tested for leaks using diesel fuel upon installation and at. least weekly thereafter. Operational tests and crew drills will be conducted daily. Primary well control will be maintained by over-balancing formation pressure with a column of drilling fluid. Automatic and manual monitoring equiument~ will be installed to detect any abnormal variation in the mud system and drilling parameters. A mud logging unit manned by experienced personnel will be in continuous use while drilling intervals where hydro- carbon are suspected and will monitor formation pressures and hydrocarbon shows. In the event that the well kicks, the BOPE will be used to shut-in t~he well ~iately and confine the Pressure within a closed system. The casing progr~m is designed so any anticipated formation pressures can be Page 6 of 1t shut-in at the~ surface' without breaking down the casing shoe. The Company representatives assigned to the drill site have had exter~sive training, including industry seminars, ~orkshops and natiop~lly recognized well control courses at louisiana State University and Oklahoma University, together with actual experience in controlling and killing kicks. Such traJ_ning is an on-going program of the Company. These personnel will be further supported by well trained drilling crews approved by the C~y. Pressure resulting from a kick will be circulated out using the balanced bottom hole pressure method and the well will be restored to its normal · operating condition. In the unlikely event that secondary control of the well is lost and premature, well flow occurs, the Conloany has at its disposal Specially designed equit~nent and a blowout contingency plan, experienced b~ck-up personnel, a c~ting unit on call at all times, and two rigs operating in the Prudhoe Bay area which can be utilized to mix mud or drill relief wells. A description of the Conloany's current blowout prevention training program together with a copy of its "Drilling Operations Blowout Prevention Manual" is available for inspection by appointmemt. 14. SPILL P~ION CONTROL AND coUNTERMEASURES In addition to a portable spill countermeasure building containing sorbent materials ar~ clean up tools, the contractor will have located at or near the well site items of heavy equipment such as dozers, front-end loaders, vacuum trucks apxl graders, if a spill should occur in spite of the preventative ~asure previously described, this ecfdipnent will be available to repair or construct additional containment berms. Additional equipmemt and sorbent materials is readily a%~ilable from Company supplies in the Prudhoe Bay area and via air and road t~ansport from Anchorage. Page 7 of 11 Since the well ~d is surrounded by bottom-fast sea ice, snow berms can easily be erected to Contain any spill reaching the ice surface' After containment clean up is benefited by low ten~eratures and abund_ant supplies of snow. Emphasis will be given to 'training personnel including Contractor's personnel, in how to avoid spills. The Company employs a full-time environmental engineer who will monitor all operations to insure compliance with enviro~tal regulations. 15. FLOW TESTING In the event hydrocarbons are encountered in this well, a flow test is expected to be conducted. Any fluids produced during a flow test' will pass through a separator from which gas will be flared and any liquids will be transported for disposal at the Sag Delta Well 33-12-16 reserve pit (see also Section 20). 16. DRIT.IJNG RIG CAMP The camp area on an adjacent island is sufficient for a typical 60 man om~p. The modular structures are pro, tided for the safety, comfort and convenience of the occupants. 17. FOOD SERVICE The drilling contractor provides food service for the drilling camp. He is responsible for insuring that all food is from an approved source, is properly refrigerated and stored on shelves off the floor. Cleanl.~ness will be ~aintained amd kitchen and dining facilities in compliance with applicable goverDm~lt regulaqions. 18. ~TI~ OF WAftER SUPPLY AND TREATMENT (See Drawing ~A84D-B-2) Fresh water for cem=~nt~%g, rig boilers, and c~qp use will be obtained from the Sagavanirktok River within the N-l/2 N-l/2 A?E-1/4 Sec. 26, TllN, Page 8 of 11 R15E, UM. Daily usage from this source %~ill amount to 15,000 gallons per ,. · day and will be withdrawn using vacuum trucks or Rolligons traveling over ice roads. This high quality water is needed for the boilers to prevent scaling in tubes which results in high maintenance and fuel costs. This same high quality water is needed for cementing because the amount of organic material in lake water is sufficient' to make setting tines erratic. Authorization for reinstatement of this water source is granted in State of Alaska, Detk~r~t of Fish and Game letter dated July 8, 1976, under Permit ADL-73265. ~ Water for drilling fluids will be obtained from inland lakes located within the NE-l/4 SE-l/4 SE-l/4 Sec. 32, the SE-l/4 SE-l/4 SW-1/4, Sec. 29, the NW-1/4 SE-l/4 SE-l/4 Sec. 34 or the N-l/2 NW-1/4 NE-l/4 Sec. 8, TllN, R14E, UM. Approximately 25,000 g~llons will be needed daily and will be hauled to the rig location using vacuum trucks. The use of lake water for non-dispersed fresh water drilling mud rec~3ires that it be treated to remove most of the calcium, especially' in the late winter when the water quality becomes very' poor. The poor quality is the result of both organic and inorganic impurities in the water being rejected as ice forms. These rejected impuri~es concentrate beneath the ice and by spring, the calcium concentration can be 600 to 1000 ppm. This lake water is obtained under authority of Permit No. A~L-72121. Camp water will be made potable using a Marina ADS water treatment facility enclosed in a skid-mounted, insulated steel building. A hypo- chlorinator installed in the treatment facility will inject chlorine into Cae raw water to control algae and bacteria ~nd to precipitate nv~nganese, iron and hydrogen sulfide. A series of filters sm.d a centrifuge will then remove sediments, iron and manganese, and also any taste, odor and Color. Page 9 of 11 The w~ter will th~n ~ss through a water softener where calcium and mag, nesium ions will be removed. Treated water will be stored in hot ~rater heaters and in storage tanks located throughout the camp. The. backwash water from the' treatment plant will be disposed of ~n an onshore pit (see below) utilized for the sewage treatment plant effluent. 19. METHODS OF HANDLING WASTE DISPOSAL Waste material will not be permitted to accumulate at the drilling site. In general, burnable w~stes will be disposed of in a Comptro A-10 1001b/hr inc' ~mnerator on site, and other w~ste material will be~ transported away from the site on a frequent basis for disposal in an approved location on land. Garbage, noncombustible trash, ash from the incinerator, and. other solid wastes will be transported to an approved waste dispoSal facility. Sewage will be treated by the ca~p physical-chemical treatment unit, a 7,000 GPD MET-PRO waste-water treatment unit, model-IPC 14000 $5990-1. Effluent from this unit will be cholorinated prior to discharge at an upland pad located at Sag Delta Well site 33-12-16, approximately 4.5 miles from this site, and sludge will be incinerated on the pad. Used drilling fluid will be processed for reuse if feasible; otherwise it wil1 be transported to land for disposal at Sag Delta (33-12-16) waste pit. Drill cuttings will be transported to the Sag Delta (33-12-16) waste pit. ~ See the attached chart and flow diagram for a more detailed description of the above procedures, which are intended to eliminate all intentional discharges on the pad or sea ice. 20. AIR POLLUTION The incinerator and diesel powered generators on the rig site (over 250 KV capacity) are permitted with the State Department of Environmental Conservation. No other equipment should be a source of air pollution. Page 10 of 11 Should hyd~~bons be encountered, and flow testing deemed necessary, an appropriate permit will first be obtained from the DePartment of Environ- rr~_n~:n_l. Conservation. 21. PLANS FOR RESTORATION OF THE SURFACE Upon final completion of all drilling operations, this well will be plugged and abandoned in compliance with all state regulations if con~ mercial ~_m_ntities of oil amd/or gas are not found. Abando~t will include setting cement retainers ar~ cement plugs above all hydrocarbon producing fozmations and/or casing liner laps. The conductor pipe and surface casing will be cut-off at the mud line and a fifty foot ~cement plug placed inside. The ~0oden crib cellar will be removed and the drill site thoroughly cleaned of any refuse. The surface of this island will be shaped to remove the containmemt berms and pits, making the drill site resemble the natural island. S.hould the well be capable of oil and/or gas production which will justify develo[m~nt wells and production facilities, it -will be left in a suspended condition. This application is not intended to cover the estab- lishment of production facilities, should any be required. Page 11 of 11 April 18, 1979 Mr. John A. Reeder Senior Attorney Sohio Petroleum Company Pouch 6-612 Anchorage, Alaska 99502 RE: Request for confidentiality of well data pursuant to AS 31.05.035(c): Sohio Petroleum Company Sag Delta #3, Niakuk #2A, Sag Delta #2, and Sag Delta #2A wells Dear Mr. Reeder: By letter, dated March 14, 19.79, Sohio Petroleum Company requested that the well data and reports submitted to the State be held confidential for a reasonable time after the disposition of unleased lands in the vicinity of the wells. The well data are due for release on the dates indicated below, unless the period for confidentiality is extended in accordance with AS 31.05.035(c) as amended by HB 915 during the last legislative session. 4/22/79 4/29/79 5/26/79 Each of the referenced wells is located on a state lease which is adjacent to or near unleased state acreage. In my judgment, the well data and reports which have been filed with the State contain significant information rele- vant to the evaluation of adjacent and nearby unleased state lands. Therefore, all data from these wells submitted to the State pursuant to AS 31.05.035(c), as amended, shall be kept confidential until after the issuance of State of Alaska oil and gas leases in the vicinity of the wells. Commissioner cc: Hoyle H. Hamilton Tom Cook ¢ 10-J9 LH Mr. John A. Reeder Senior Attorney Sohio Petroleum Company Pouch 6-612 Anchorage, AK 99502 RE:: Request for oonfidentiality of Well daha pursuant to AS 31.05.035 (c): Sohio Pehroleum Company Sag Delta #3, Niakuk #2A, Sag Delta %2, and Sag Delha #2A wells Dear Mr. Reeder: By letter, dated Ymrch 14, 1979, Sohio Petroleum Company re~luested tJ~at the well data and reports sutmtitted to the St~te be held oonfidential for a reasonable time after the disposition of unleased l~ds in the vicinity of the wells. The well data are due for release on the dates indicated below, unless the period for confidentiality is ext~ded in accordance with AS 31.05.0.35 (c) as amended by HB 815 during l~e last legislative session. 4/22/7~"' 4/29/79 5/26/79 1/26/80 IO-J2LH .Each of iuhe referenced wells 'is located on a Stake lease which is ad- jacent to or near unleased State acreage. ]~ my judgment, the well data and reports which have been filed with t~e State contain signi- ficant infonnation relevant to the evaluation of adjacent -and nearby unleased State lands. Therefore, all data from these wells su~m~itted to the State~ pursUant to AS 31.05.035(c), as amended, shall 1~ kept confidential, until after the issuanoe of State of Alaska oil ~d gas leases in the vicinity of the wells. sincerely, Robert E. I~J2esche cc~nis sioner cc: tbyle H. Hsmilton: ~qTon~s BP ALASKA INC. CONFIDENTIAL State of Alaska Department of Natural Resources Division of Oil and Gas Conservation 3001 Porcupine Drive Anchorage, Alaska 99504 P.O. BOX 4-1379 311 I - C - STREET ANCHORAGE. ALASKA 99503 TELEPHONE (907) 279-0644 April 13, 1977 Attention: Mr. Hoyle H. Hamilton Director Gentlemen: Well Number Niakuk #2-A Enclosed, in duplicate, is Form P-4, Monthly Report of Drilling and Workover Operations for the above described well for the month of March 1977. Very truly yours, BP ALASKA INC. G. ~. Tayl~riJ Manager Operations GDT: j le Enclosures cc: Well File #17 CONFIDENTIAL F~rm lq'o, P--4 REV. ~- I-?0 STATE OF ALASKA SUBMIT II~ DU?L1CATIg OIL AND GAS CONSERVATION COMMITTEE MONTHLY REPORT OF DRILLING AND WOR'KOVER OPERATIONS WELL ~FELL ~. Na_~E OF O~'~P~TOa BP Alaska Inc. 3. ADDRESS OF OPEP~R Wildcat P. O. Box 4-1379, Anchorage, Alaska 99509 4. LOCATION OF WFJ. J- At Surface: 1726' NSL, 1130' WEL, Sec. 26, T12N, R15E, UPM ~ API'NUA{ERICAL CODE 50-029-20180-01 LEASE DESIG~A~ON AND S~IAL NO. ADL - 34630 Surface ADL - 34625 Bottom Hole T IF INDIART. AL'OTI,~;E O1~ TRIBE NAME 8. L~IT FARA{ OR LEASE NAME WELL Niakuk #2-A l0 FIF/~D A>ID POOL. OR WILDCAT Wildcat SEC, T.. R., l~{ (BoTToM HOI~E O~~ Sec. 23, T12N, R13E, UPM 1~.. PERMIT ~O 176.79 13. REPOttT TOTAL DI~IPTH AT Ea~D OF MOb/T%~I. CH~NG~ IN HOLE SIZE. CASING A~ CmF~TI~G JOBS INCLUDING DEPTH SET ~ VOL~ USED. P~O~TIONS. ~STS ~ ~SULTS FISHING JO~ JL~K ~ HOLE AND SIDE-~ACKED HOLE ~D ~Y O~R SIGNIFIC~T ~G~ ~ HO~ March, 1977 Drilled 8-1/2" hole to 12,564'. Ran wireline logs. Ran 110 joints 7" 29# N-80 Buttress casing to 12,564' and hung as a liner at 8297'. Cemented with 1875 sacks Class "G". Inflow tested lap - Okay. Perforated and drill stem tested 12,222'/12,294'. Installed 7" EZ-drill bridge plug at 12,170' and capped with 50 sack cement. Ran 9-5/8" bridge plug to 8204'. Layed down drillpipe,displaced top 2000' to diesel. Installed wellhead cap. Released rig 1800 hours, March 30, 1977. i, StoNED ....... ~:~ ink / TITU~ Manager 0peratio. Bs ..... ~, 'J!'~ 1~/'] ¢;- I). 'F~vlrtr '" .......... NOTE --Roi)art on this f-arm ils required for each calendar month~ regardless of ~h~ status of operations, and must bo flied In duplicate with the oil and gas conservation committee bythe 15th of the ~ucceeding month, unle~ otherwise directed. :' ' ' 9EFARTMEttT OF r:ATURAL RESOURCES~': ' .......... T- . b..iston of 0tl and Gas Conservatl, . To: ~ Pedro Denton " Chief, Minerals Section, DMEM FROM: · DATE : April 6, 1977 Hoyle H. Hamil ton /~,~ Dt rector, DOGC//~' _. SUBJECT: Verification of paying quantities test, BP's ADL 34625, Niakuk Well On March 26, 1977 a petroleUm engineer, Russ Douglass, from this division was on location at subject well and witnessed a DST flow test for deter- mination of paying quantities capability of this well. Final data from the test was transmitted to Anchorage on March 27 at which time the data was tn~nediately reviewed and the conclusion drawn that the test was adequate to confim BP's claim that this well is capable of producing in paying quantities. Verbal approval_was transmitted to Mr. Gary Pleska of BP who requested verbal approval from sm~one with DMEM. Mr. O. K. Gilbreth was "'so informed'of the determination of the Division of Oil and Gas Conservation and of the recommended approval of this paying quantities test and he in turn gave verbal approval to BP's Mr. Roger Herrera on that same day. This memo is to confirm the ~ietermination and the verbal recommendation of approval presented on March 27, 1977 that this well is capable of producing hydrocarbons in paying quantities. ~/L(;S:bJm ~.. . .. _ 02~01B STATE of ALASKA 3.14 500.41 TO: ~ FROM: I~Dyle Hamilton, Director Division of Oil az~C~s Pedro Denton Chief, Minerals Section DATE : ~'~x::~ 31, 1977 A/;f'~,>-A sag--De~I~--~-~-I1 (33-12-16 ~-~--~ Sag Delta ~. 4 (36-12-16) Enclosed are copies of letters frcm BP Alaska Inc., requesting production certification of Niakuk Well #2A and Sag Delta #1 well. Please confirm whe~ these wells are capable of producing in paying quantities. Also enclosed is a copy of a BP letter dated March 30, 1977, informing us of drilling operations being col~ucted on lands covered by a lease wbgse primary tezm er~s March 31, 1977. May we have your confirmation of this so we may proceed accordingly? UNNAMED OIL FIELD NORTH NIAKUK ISLANDS AREA ARCTIC NORTH SLOPE SOHIO - OPERATOR LOCATION DISCOVERY WELL DISOOVERY DATE PRODUCING FOR~ITION OIL POOL TYPE WELL Oil Producer RESERUDIR DATA Reference Datum - (Subsea) Original Pres__~e - psia Oil Gravity API GOR (SCF/STB via test) Temperature - F ~oss Pay %hickness-Feet Permeability - md Swi - % Productive Area- Acres Method of Operation Suspended Offshore, North of Niakuk Islands Schio Niakuk 2-A March 26, 1977 Sag River Undefined No. of Wells 1 56 i _1 I I ooI I__ I I I I ~ I ADL-512819 ', II ItT BduNDAR¥ , ADL- ;51~820 I I I I ~,~ SOHIO NIA KUK-- .~ I I I I GULL S ST - I I I I l~"Gu I I Island I I ~co I GULL rS. ST. - 2 I I I I I I I J r/OE ARCO TR T3C I E. BAY ST-~', I ,. x '7-1 Y I I I' I NIAYUK- I ~-,T I ,okuk Islands SAG DELTA ~ BP I I I I ADII- 312827 SAG DELTA- 8 ~1 B STATE of ALASKA DEPARIT~ENT OF ,~ATURAL RESOURCES Division of Oil and Gas Conservation TO: ~-- Hoyl e H. Hami 1 ton ~~"- Di rector Thru: Lonnie C. Smith ~J~'~<~- Chief Petroleum Engineer Russell A. ,Douglass ~t> FROM: Petroleum Engineer DATE "March 29, 1977 SUBJECT: ~,-~itness Drill Stem Test #1, BP Niakuk 2A ~rch 24., t977 thr°_ug~ _Sunday., t-~,arch 27, 1977- Traveled to the North Slope on the 24th. Purpose of my trip ~as to ~,~itness 2^° testinQ on the BP Niakuk Due to the confidentiality of the results, a detailed report has been prepared for our confidential files. In su~~: I witnessed testinQ of BP Alaska's Niakuk 2A well during 'the ~erio~' ~Fch 24 through March 2~, 1977. R~JD ~ b Jm BP ALASKA INC. 31 ! 1 - C - STREET · TELEPHONE {907) 279-0644 March 28, 1977 Mr. O.K. Gilbreth Director Division Minerals and Energy Management Department of Natural Resources State of Alaska 323 E. 4th Avenue Anchorage, Alaska 99501 MAILING ADDRESS: ANCHORAGE, ALASKA 99509 ADL LEASE 34625 - Niakuk Well No. 2A (23-12-15) Dear Mr. Gilbreth: I herewith confirm the content of our telephone conversation of Sunday, March 27th, 1977, in which you indicated, on behalf of the State of Alaska, acceptance of the results of the test carried out on Niakuk 2A (23-12-16) on March 26th, 1977, as sufficient to hold lease ADL 34625 in full force and effect beyond its primary term. The test was witnessed by an officer of the Department of Oil & Gas Conservation, and all details of it were available to the Director of that department. Further, by means of this letter, BP Alaska Inc., on behalf df Sohio Petroleum Company, requests your formal certification of Niakuk 2A (23-12-16) as a well capable of producing oil or gas in paying quantities sufficient to hold Lease 34625 after the expiration of its primary term on March 31st, 1977. For reasons of safety, in particular, due to the approach of Spring breakup and its effects on the Niakuk Island well site, the Niakuk 2A well is being temporarily suspended in a manner approved by the Division of Oil & Gas Conservation. We request your confirmation that such action in no way adversely affects the extension of the lease term established by the well. Yours truly, RCH:lpb Roger C. Herrera Exploration Representative BP Alaska Exploration Inc. cc: Pedro Denton ~HoYle Hamilton RECFIVED MAR 2 9 t977 TO: Niakuk 2A file (Confidential) FROM: Russell A. Douglass Petroleum Engineer Tbursday, March 24, 1977. MEMO RAN DUM Date: March 29, 1977 Subject: DST #1, Niakuk 2A, BP Alaska, North Slope, Beaufort Sea Received a call from Brian Davies with BP Alaska. He informed us they were rigging up to test the Niakuk 2A well on Friday. I caught the 3:30 PM BP charter to Deadhorse in order to witness the testing of the well. When I arrived on lbcation they were logging. They were unable to get to bottom with their logging tools so had to pull out and run the drill string in order to con- dition the hole. Friday, March 25, 1977. Received a call from Kirk White with Arco. He informed me they were ready to test the ball valve in DS I-2. Traveled to DS I in order to witness the testing. After two unsuccessful attempts to test the ball valve I returned to~iakuk 2A with Neil Booth. While I was at DS 1 they had completed logging operations and made one perforating run. They were going in with the second set of guns when I got back about 3:30 PM. On' the second run several charges failed so Schlumberger was making up another set of guns for a third run. Finished perforating after dinner and were making up the DST tools about 10:00 PM. Going in the hole with test tool assembly and cushion of meth~'anol and water (50/50 mix). Saturday, March 28, 1977. Waived a ball valve test on Arco DS 2-10. Minos Hebert cai led and I told him to go ahead and test and we'd catch it at a later date if possible. Started DST #1 on Niakuk at about 1:30 PM. 5 minute flow with a 1 hour build-up. In the second flow cushion reached the surface after 48 minutes. Average flow rate was 1430 bbls fluid/day. '~ Reversed out produced fluids and cushion while allowing 2 hour buildup. All samples taken during the reversing stage were contaminated with cushion and mud. Hopefully a representative formation fluid sample would be caught below the DC[~P. Started pulling test string. Sunday, March 27, 1977. Bottom hole sample to surface about 7:00 AM. Allowed sample to warm up to 75+°F. Centrifuged several samples which showed no more than 0.2% BS&W. Oil was 44°APl @ 76~. Called Lonnie at home and used our code to report the results. A BP DST program, my notes and a schematic of the well are attached. I stayed the night at the BP base camp and returned to Anchorage on Monday, March 28, 1977. In summary I witnessed DST #1 on BP Alaska's Niakuk 2A. BP ALASKA INC. P.O. BOX 4-1379 3111 - C - STREET ANCHORAGE, ALASKA 99503 TELEPHONE {907) 279-0644 March 8, 1977 CONFIDENTIAL State of Alaska Department of Natural Resources Division of Oil and Gas Conservation 3001 Porcupine Drive Anchorage, Alaska 99504 Attention: Mr. Hoyle H. Hamilton Director Gentlemen: Well Number BP Niakuk #2-A Enclosed, in duplicate, is Form P-4, Monthly Report of Drilling and Workover Operations for the above described well for the month of February. Very truly yours, BP ALASKA INC. J:.'/.t,,~ F. J.~' Venn Prudhoe Bay Fields Manager FJV:jle Enclosures cc: Well File #17 RECEIVED M^R 9 Ft)~m No, STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE MONTHLY REPORT O'F DRILLING AND WOR'KOVER OPERATIONS Wildcat 1. o,L [] 0,e [2 WrLL WELL OTHER 2. NA~.-. OF O~'~.ATOR BP Alaska Inc. APl NU'MER1CAL CODE 50-029-20180-01 LEASE DESIGA1ATION AND SE1RIAL NO. ADL- 34630 Surface ADL - 34625 Bottom Hole 3. ADDRESS OF OPERATOR P. O. Box .4-1379~ Anchorage., Alaska 00509 4, LOCA~ON or WELL At Surface: 1726' NSL, 1130' WEL, Sec. 26, T12N, R15E, UPM SUBMIT IN DU?LICATE 7 IF INDIA~, ALO]"'UEt~ OR TRIBE HAME 8. L,~IT FAIR~ OR LEASE HAME g WELL NO Niakuk #2-A 10 FIELD A_ND POOL. OH WILDC~¥F Wildcat 11 SEC. T., R., M. (BOTTOM HOI~, om.rEcrrv~ Sec. 23, T12N, R15E, UPM 1~.. PEt~IIT NO 76-79 13. REPORT TOTAL DEPTH AT END OF MONTH. CHANGF_;S IN HOLE SIZE. CASING AND CL-ME, NT!NG JOBS INCLUDING DEPTH SET AND VOLU]VIESUSED, PERFORATIONS. TESTS ATqDRESULTS FISHING JOB~ JULNI{tN HOLE AND SIDE-T]RACKED HOLE AN'D ANY OTHER SIGNIFICANT CH. ANG~ IN HOL~ CONDITIONS , .February, 1977 Drilled 8-1/2" hole to 10821'. Could not get away from old hole. Set EZ- Drill plug at 9895' and pumped 150 sacks "G" cement through EZ-Drill plug. Perforated 8-1/2" holes at 8950',set':EZ-drill plug at 8913' and squeezed with 300 sacks Class "G" cement. Ran and oriented Eastman permanent Whipstock at 8915'. Milled window 8891' to 8900'. Lost window. Milled section in 9-5/8" casing from 8830' to 8868'. Ran under-reamer 8830' - 8861'. Placed 130 cu. ft. cement kickoff plug through drill pipe at 8868'. Ran Dynadrill and side- tracked through window. Drilled 8-1/2" hole to 9025'. RECEIVED Dlv, lston 0l Oil & O~ ~.~w~tt0n hereby ce~ffy t.,h~orego~'~g is true =TU~ Prudhoe Bay Fields MaBa__g~ema= "/ ~[z~tc~ (~77 NOTE--Report on this form is required for each calendar month1 regardless of the etatus of operations, and must I~ filed In duplicate with the oil and gas 'conservation committee bythe 15th of the succeeding month, unle~ otherwiia directed. BP ALASKA INC. CONFIDENTIAL State of Alaska Department of Natural Resources Division of Oil and Gas Conservation 3001 Porcupine Drive Anchorage, Alaska 99504 Attention: Mr. Hoyle H. Hamilton Director P.O. BOX 4-1379 31 I I - C - STREET ANCHORAGE, ALASKA 99503 TELEPHONE (907) 279-0644 February 3, 1977 Gentlemen: Well Number BP Niakuk #2A Enclosed, in duplicate, is Form P-4, Monthly Report.of Drilling and Workover Operations for the aboVe described well for the month of January, 1977. Very truly yours, BP ALASKA INC. G. D. Taylorl Manager Operations GDT:jle Enclosures cc: Well File #17 R~"vL $- I-?0 STATE OF ALASKA su.~rr n~ Dm:,UCATr. OIL AND GAS CONSERVATION COMMITTEE MONTHLY RE!PORT OF DRILLING AND WOR'KOVER OPERATIONS o,. I-] o,, [] o,,,-, Wildcat W~LL W~-LL NAME OF OPI~:tATOR BP Alaska Inc. ADDRESS OF P. O. Box 4-1379~ Anchorage~ Alaska 99509 4. LOCA~ON ~F W~LL At Surface: 1726' NSL, 1130' WEL, Sec. 26, T12N, UPM API N~ERICAL ~ODE 50-029-20180-01 LEASE DESiG~A~ON AND S~IAL NO. ADL - 34630 Surface ADL - 34625 Bottom Hole 7 IF INDIAI,~ ALOTT'EE OR TRIBE NAME 8. L,~IT FARA{ OR LEASE NAME 9 WELL .~'O Niakuk #2-A 10 FIELD Y~D POOL. OR %VILDCAT ~Wi]dnat , SEC. T.. Ft.. IV[. (BOTTOM HOi~E O~FX~TrVE) Sec. 23, T12N, R15E, UPM 1~. PERMIT NO 76-79 REPORT TOTAL DEPTH AT END OF MON~'IM. CHANGES IN HOLE SIZE, CASING AND CI~V[F~'WTING JOBS INCLUDING DEPTH SET A/W~) VOLI31VIF~ USED. PF~RFORATIONS, T~STS A/YVD RESULTS FISHING JOB~ Jb~4K IN HOLE AND SIDE-TRACKED HOLE A2JD A. NY OTHER SIGNIFICANT CI{A. NI3;ES IN HOLE CONDITIONS January, 1977 Start operations 1200 hours, January 3, 1977. Drill out bridge plug @ 2100'. Ran 54 joints 9-5/8" 47# controlled yield N-80 buttress casing and tied back from PBR at 2108' to surface. Arctic Pack 13-3/8" x 9-5/8" annulus through F.O. @2064'. Mill window in 9-5/8" casing 10,020' to 10,075'. Lay kickoff plug 140 cu. ft. Class G. Clean out cement 9820' to 10,025'. Stuck pipe 60' up into 9-5/8" casing. Pull loose. Dynadrill to 10,079'. Run drilling assembly to clean out. Stuck pipe 60' up into casing. Backoff. Fish - pull loose-drill 8-1/2" hole to 10,144'. 14. I he.by ~ify sm~ NOTE oil u~d STATE of ALASKA Division of Oil and Gas Conservation TO: ~foy!e Director Chief Petro!e,~ Engineer FROM: Harol~ R. }Iawkins Petroiem~tt Inspector-, DATE : January 11, 1977 SUBJECT: Witness BOP Test ]'3P of Alaska, Niakuk Sec 23, T12N, R151OJ, Permit No. 76-69 Oec~~~=~ 31, 1976. Jack n~a-rr- ~ operator, for ~q.P ~ picked. ~e .... up at ~~g DS 9-~d took me over to .....~P base camp to standby r. or~ their BOP tests on Nikakuk 2-A for me 'to witness. Janua~ry 1, 1977. Jack Bart 'hook me over to !qiakuk 2-A and ~d 6r-~-~red up tilesta~r~r~'- and ,~za,_~= r_a,~.y~ ~ to ~e~t~ ~)O.... ,~r~ ~ but when ! observed ~eir pressure on the stack it was only 2500 and the koom. ey test pump would, not pressure any higher. ! told ~hem ! had to witness a 5000 psi9 test ~3~.fore I could okay their test. s. A wkm valve on the kill line had a grease._, fitting missing- and was leaking even at 2500 psi. They had. no fittings at the sm~.,= Jack Barr =pent several he,irs huntino' for a ~rease fitting and the crew was working on the koomey pump. ~~ 2, 1977. _~hey t~hought they hac]. the koomey pump fixed 5~~ f %~rveci it pressurin~ up it still would not pump up to 5000 psi~ although it pmmped up enough to see that the lower pipe rams were not holdin~ and leaked. ?~hile they replaced rubbers on the lowerp~p~ ~ rams, Jack Bart went and c~ot ........... another koomev oumr> ;~:ro~.. another Parker rig. It also would not work after several hours trying to make it work ~h~ _. . = ..... y ~ot one more koomey pi.linD and spent several hours with it and it also would not pressure up. This was three koomey pumps in a row. oan)3~ ~, :!_~77. Fir, all- the nicked un ~ oane centrifugal pump somewhere an~! we starte~, testing. .Lhe lo~er p~Pe rs~s were paired. The upper pipe rar~s were tested girst this time and held . che~:< valve on the 5000 ps~ nkav Also the , c~ ' .~1 line was tested to 5000 psi and ~he hydraulic con~rot relief valve was tested to 5000 psi okay on the choke line. Tested next was the insic~e kill ~al~re~, .. -~b.l~n'~ was ~ ~,~km that had~. a qrease._ fitting missing and was ' C] .~. . repa.tre.~, and was tested to 5000 osi okay The manifold was next. All valves held 5000 psi okay,<. There were nine cameron vel. yes, one..~ositive chok~, one manual choke an~,_~ '~ a Swaco ~ ,, which were all tested separately to 5000 ~ · n ~e.:,te,~. to 5000 The test stem was pulled and the ..~l].n,..,,. rams were ~ ~- "~ . ~...,: test stem was put r,ack in and t;he lower pipe rams were ~asked ~'~'~' leaked o~e_a~oz for ~, na~. th~ crew hook up the m~,,~ n~amp BP'S Niak~ 2-A -2- BOP test January 11, 1977 to the kill tine and wed a rig p~m~p to give lower pipe rams a little kick to help seal ~hem. It worked and the lower pipe rams held 5000 psi okay. The annular preventer was tested next but leaked around the aameron clamp on the %~derside of the annular preventer. They used a hammer wrench and tightened the clamp using the eat line. The preventer was retested and held 2500 psi okay. I went over to BP's Sag Delta No. 2 on Parker Ag with Jack Bart and met Lee Simmons, who was the operator for ARCO, and checked out the diverter systemwhich will be another re.port. I did this while Rig 92 was rigging up to test the upper and lower kelly. Jack Bart and I went back over to Rig 192 at the Niakuk site and I witnessed the testing of the upper and lower kelly that tested to 5000 psi okay. I witnessed testing for 38 hours. The well sign was up and all data okay. The pits were open but bermed with snow. Jack Bart said ~ pits would not be used unless it was a dire emergent, that ~heywere to haul off all -~olatile fluid. There was a steel fuel tank but not be~d. They had a ball valve and dart valve on ~he floor that was in good shape.. The N2 backup that is required was not on lc~atlon~ and manifolding ~or the' nitrogen backup was not done. The Parker pusher ordered the back- up bottles b~t ~y sent left handed connections which are. not supposed to be hooked up to non-inflatable products. Also one bottle that was s~d nitrogen for backup had left handed threads. I told the operator ~hat they should not hook this bottle to the back~ system. Jack Barr, operator for BP; and Gene I~ill, S~rintendent for Parker, were advised by me and agreed they would not. The accumulator bladder precharge bottles had several bad leaks on the bott~ of ~e ~ttles. I pointed this out to Jack Bart. He had these repaired and they are okay now. The accumulator ~aster gauge had 2500 psi. Both the master controls and remote controls on the floor accuated the BOP'$ properly. In su~m~a~, I witnessed the testing of the blowout equipment on Niaku]~ 2~ for BP of Alaska. All ~i~nt in very good condition and working properly except the nitrogen backup bottles. Jack Bar~, operator for BP, is to give u~ a call by January 6th that he. has installed M2 backup. Attachment A%tac~nt to B~P ' s Niak~ 2-&, BOP test. Jan.uar~6, 1977.. Jack Bart, ~er. ator for BP, calle~_~ our. office ~m~~~-~Norman that the nitrogen backup bottles ~or Niak~ 2-A were manifolded up and there were 2050 psi in each bottle. (~ ( ) 1. Well Sign ~) ( ) 15. /J)Jl~,Casing set @J~A~P~£$~7.0~ .(~) ( ) 2. General Housekeeping (~) ( ) 16 ~-~ fluid-( )wtr.-~--~ )mud '(4 oil ~.!j~) ~.' (') 4. Ri~ '~?~.;:~; ( ) Safet~ Valve Tests ( )~'( )' F'.~. 5. Surface-No. Wells ( ),.' ('"~.)'i/~i~ 6. SubSurface-No. Wells · ~"~ (') Well' Test Data ( ).!~i ( .?)]'~:i':" 7. Wel 1 Nos. , , ( )~?' ( ) 8. Hrs. obser , ., ( )' ( ) 9. BS&W ,--, ,.-- ( ) ( ) 10. Gr, Bbl's. ( ) Final Abandonment 3~,~ReserVe Pit-(~Open( )filled 17. Master Hyd. Control Sys.-~~. sig 18. N? btls. , .,~' pslg 19 REmote Controls 20 Drilling spool yt///?-~o~tlets 21 Kill Line-{)F) Jheck valve 22. Choke Flowline (~Y) HCR valve 23. Choke Manifold No valvs~_~flgs~A~aui)~ 24 Chokes-(X)Remoteal)pos'. (~Adj. 25. Test Plug-~)Wellhd( )csg( }none 26. Annular Preventer .j~('~i~ psig 27. Blind Rams~6~psig (x) ( ) ( ) ll.. P&A Marker (X') ( ) 28. Pipe RamsFy~ psig (~) { } 12. Water well-( }capped( }plugged {X) { ) 29 Kelly & K~elly-cock~psig { } { } 13. Clean-up (K) ( ) 30. Lower Kelly valves-~j~ psig ( ) ( ).~ 14. Pad' leveled ~ ~-~ ~) ( ) 31. Safety Floor valves-~k')BV (X)Dart Total inspection observation t'ime~ ~/days Total ~umber leaks and/or equip, failures ~ Remarks.~jF~ p ~ ~ ~ ~/~'n ~ PP~ PYP~ h~y, ~~Z~~ ~A ~ ~P~AdP) ~ ~ ~ ~ 1lAn ~ n~ z-o~~r~ ~ ) ~o ~x~ ' ,O,~,~--,~W~ 'd~)<~ ~ + ~ cc: .or w en ' ~2-001B STATE of ALASKA Division of Oil and Gas Conservation Director Thru· Lonn ie C. Chief Petroleum Ln ~lneer FROM: ~-~,.,o~11 A Douglass Petrol eum Engineer DATE .. December 90 l,-~ SUBJECT: b~itness layinc! of ~ercI~l it~? I~at Saturday, December 11, 1~76 .-Left Ancnoraee a.; :-~.:..,,~: h.F~ on p? cne~ruer. ~d geadjlO~ a~ ~07~}.~.. PurPose of'my'trip was to ~,~itness installation of an impern~able r~;embrane (" ' ,,ercu!ite ?at) on the ~iakuk 2A location. ~,;!et with Ji~; ?~cGee, BP consultant, and ~ocer Hyde, Herculite representative, at the geadhorse airport. t~hile waiting for the plane to unload, Jim, Ro?er an~l I discusse~'; the Herculite t?Jat. The operational temperature range is -4~}° F to lf;C)° F. At the time ! arrived in Deadhorse, the temperature was a rain,is 3F; and the wind ~:as blowing so the chill factor was -50° F. Ro~er said the only prob!er~'~ caused by the low temperature ¥,¢oL;ld be a cold crease. This crease can be corrected with application of heat to s?ooth out the creases while laying the mat. ~ie proceeded to the BP operations center t~here we waite~ for the ~erc~lite crate. Picture No. 1 sho~s the crate i.n the BP stores warehouse. The crate contains one mat, 10g feet by 15o feet. Jim in'formed us he still had ~. measure and drill a rat hol~-~ on the ~iakuE location, so the mat could not be !aid until Sunday. .~un_d~, gea=,~,Der 12, 197G - TeI~]peratt~re was up to 15 below, hL.,.t there ~ still ~ ~c~ ~,i~ t~ 1ay the herc~lite.~ Roger an~i Jir'~ worked the logistics. Ji~-~,,c,~"~ a space heater ~?hich he would use to ~--~p.~... ........ Herculite mat warm while waiting to be laid. The n~at could be spread by the drilling crew and held in place with sacks of weight J~aterial while the dril! lng mats were being placed down by crane. !~ondAb~, ,2~cember 13, 1976 - Temperature was still rising, a !inht snow was falling and the wind was r~inimal. Jim, Roger and I not an early start and were oJ~ the Niakuk .pad shortly after ~:f!n AH. Jim wa~ted tn sprua~ the Herculite so~etime bet¥,,~-~en., lO-nn. _.~,~: ,~A~.i~ and .,:..~,~-,.mn ,P"~: since that is the i ightest part of the day. . i~!hen we arrived on 1 ~' ='~ , ~ey were still n " . oca~on, :.~ra~n~ th<~ pa(i T~:~,~ crane ~as notthere and the weight ~aterial wa~., stil~, net there. The Herc~lite crate nac~ proceeded us and the crew was setting uo the sr]ace heater s~ they could keep it ¥~am?~. Pad preparatinn (Pict~res ~'.~os. ~ and 3) m~til after lunch and the weinh* ~ateriat ~ii~ not arrive until afLer 1 H' Hamilton 2- December 28, 1976 Started laying the Herculite shortly after l:O0 PM. (Pictures No. 4, 5, ~). TOOk less than ten minutes to spread the H6rCulite' ~PiC~'u-re ~hows the ~rculite With the weight material holding it in~~ Twenty minutes after the Herculite was in place, the wind started up and would have bl~ the Herculite off location if it hadn't been held down. We left the location about .2:.00 PM. Three of the drilling rig mats were al ready placed when we 1 eft. i walked on the Herculite and could see no indication of damage. The drilling crew was instructed not to drive over any portion of the mat or drag any material over it. That was why they were laying the rig mats with a crane, to minimize any damage to the Herculite. I called Lonnie Smith from the BP operations center and told him the job was complete and that I would be flying back to Anchorage Tuesday. Tuesday,. Dec,er 14, 1976- Returned to Anchorage via BP charter, arriving ai~' 3.--00 ~ a ~'m'~ a i rport. In S~u~ary: I witnessed laYing of the Herculite membrane on BP's Niakuk 2A locati6n, North Slope, Alaska. RAD:bjm Division of ~erals & .Enex'Gy~ Ngan- agem~t 323 £ 4~H A'/£NIJE Decenf0er 22, 1976 BP A!asP~, inc. P. O. Box 4-1379 A_nctx)rage, Alaska 99509 Attn: Herman A. Sct~nidt District ~ .~Dh-~S '76-106 Nia>~n~k ~2A Well (23A-12-15) ADL 34625 The operations outlined in your lehter of Octm..hosc 18, 1976 a~4 November 30, 1976, are hereby approved subject to the following stipulatioi~s: 1. BladLng or re~ovai of vegetative cover is prokibi~:~. 2. Ice roads shall be construcLed for all transportation opera- tions on tundra areas includj~c~ e~ais'h'.~g 'win-te~' 'trails. These roads shall .be co~zstruched amA. n-~/ntain~ in a mamner that will prevent damage to fiae tundra. Ice rcads .are not. re~fu. ~red tla~e is no v~etative cover, such as along rivo_r .b~:~s and gravel' bars. 3. No equi~ent shall ~nter or cross active (open flo%cLng) cb~nne!s of ~.tercourses and the barH.~ of t~he v~tercourse sP~ll 4. Any time ~ter April 15, 1977, the use of ground contact v~d~ic!es s.hall be subject to termination wi~d~n 72 PDurs of noki- fication by the director. 5. Drinking x-~ter stLall nmet t~.e v~ter cluali~ stam']_ards of the Division of Air ~.d Water .~iity, Department of Environmental Conseccation. 6. All operating areas s~hall t~. maintains, ed ~d u~non c~n121e'tion of operations left in a condition satisfactory, to tfi~e director. 7. No raateria! shall be dumped on or t~er the ice ~¢ith specific regard to drill mud, fluids and cuttings. ~ · .~ LO/%~S 76-106 Page 2 Decem/oer 22, 1976 8. -The reinforced membrane t~ b~ placed beneath the ~ntire drilling rig structure as a ~t of the drilling_ tknd shall be verified for p~oer installation and integri-ty by a representa- tive of ~he Division of Oil and Gas. 9. Any ~st~ater discharges must m~et A]PA's secondary treat- ment st~nd~ards; 3~g./1 BODs, 3~'g/1 suspended solids, ama 200 fecal coliforms/10 ~tl. 10. Ail putrescibie w-~stes and se~.~ge sludge shall be, incinerated in an approved unit. 'Otaher ccmmbastibles such as ~per, %~Dod ~nd cardboard may be burned in a mannar so as not to create black smoke emissions. Tin cam_~ shall be incinerated prior to disposal. Incinerator refuse shall be buried in a "false start ~!1 hole", hc~ever, if tttis is n©t feasible it may be buried in the reserve pit. A minimum' of five (5) feet of fill material shall be placed -over. this residue upon ~letion of operations. , . . Non-cc~lpustib!es such,as rubk~r, metals, drmm~, bat%er[ies, e-tc. slnall be backhauled f~ Prudhoe B~y or stockpiled at Prud!~e Bay.. in such a r~mner to promot.e future siavage .operations. 11. in the event tahat hYdrocam~bons are encountered in this ~.~mll and a flow test conducted; prior Department of Environment~7! Conservation approval shall be obtained for disposal of flo~,{ test liquids. 12. A completion re~ort ~hall be suhnitted within 15 days upon termination of operations. f ! Conservation ~cember 2'3, 1976 Niakuk flo. 2-A BP Alaska, Inc. State Permit l~lo. '76-79 G. D. Taylor Manager Operations BP Alaska, Inc. P. O. Box 4-1379 Anchora~, Alaska g95~ Dear S i r: Enclosed is th appro~d application for oermit to drill the above referenced ~ll at a location in Section 23, Township 12~, P~ange 1SE, UP)4. l~ell samples, core chips and a Nd log are required. A directional survey is required. Pollution of any waters of the State is prohibited by AS 46, Chapter 03, Article 7 and the regulations, promulgated thereunder (Title 18, Alaska Administrative Code, Chapter 70) and by the Federal Water Pollution Control Act, as amended. Prior to c~ncing operations you may be contacted by a represen~tive of the Department of Environmental Conservation. Pursuant to AS 38.40, Local Hire Under State Leases, the Alaska Department of Labor is bel g notified of the issuance of this permit to drill. To aid us in scheduling field work, we would appreciate your notifying this office wi~in 48 hours after ~the well is spudded, b!e would also like to be notified so that a representative of the Division may be present to witness testing of blowout preventer equipment before surface casing shoe is drilled. In the event of suspension or abandonn~nt please give this office adequate advance notification so that ~e may have a witness present. G. D. Taylor 2- December 23, 1976 Upon completim, a tubing plug or a subsurface safety valve must be installed and wi~ssed in case of a successful well. Please notify our division in ad~uate time-to witness the operational test of this valve. Very truly yours, Hoyl e H. Hamt I ton : _ Chai~n Alaska Oil and Gas Conservati~ Committee £~losu~ CC' Oepar~nt of Fish and ~me, Habitat Section w/o encl. ~pa~t of Envtro~ntal Conservation w/o encl. ~par~nt of Labor, Supervisor, Labor Law Compliance Division w/o encl. BP ALASKA INC. P.O. BOX 4-1379 31 I 1 - C - STREET ANCHORAGE, ALASKA 99503 TELEPHONE (907) 279-06~1, October 21, 1976 CONFIDENTIAL State of Alaska Department of Natural Resources Division of Oil and Gas 3001 Porcupine Drive Anchorage, Alaska 99504 Attention:, Mr. Hoyle Hamilton Acting Director Gentlemen: Well Niakuk 2-A (23-12-15) Enclosed please find the following documents: 1. Application for Permit to Drill Well Niakuk 2-A. 2. Proposed drilling program outline. 3. Our check in the amount of $100.00 to cover the permit filing fee. 4. Three copies of the surveyors plat showing the well location. Very truly yours, BP ALASKA INC. G. D. TaylOr Manager Operations JFV:jle Enclosures cc: Well File Roger Herrera -:~'-. SUBMIT IN TP. IPL. b~ ': Form lO-401 ' REV. 1-1-71 (O(hcI in:;t[uction reverse side) STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE PERMIT TO DRILL OR DEEPEN la. TYPE OF WORK DRILL J~] DEEPErq J~] b. TYPE OF WELL OIL GAS SINGLE MULTIPLE 2. NAME OF OPERATOR BP Alaska Inc. 3. ADDRESS OF OPERATOR P. O. Box 4-1379, Anchorage,. Alaska 99509 4, LOCATION OF WELL At surface 1726' NSL, 1130' WEL, At proposed prod. zone 2575' NSL, 630' WEL~ Sec. 26, T12N, R15E, UPM Sec. 23, T12N, R15E~ UPM 13. DISTANCE IN MILES AND DIRECTION FROM NEAREST TOWN OR POST OFEICE* 12 mi. NE of Deadhorse API No. 50-029-.20180-01 bur ILtCe --._AD._L__, -__346~_25 Bot.~m Ro~ 7. IF INDIAN, ALI.O'Iq'I{I~ OR '1'10 BE NAME 8. UNIT FARM OR LI'SASE NAME 9. WELL NO, Niakuk No. 2-A 10. FIELI) AND POOL, OR WlLDCA'r Wildcat 11.SE(L, T., R., M., (BOTTOM IIOLE OBJECFIVE) See. 23_z_T12N~ R15Fz_~ .U.PM 12. . 14. BOND INFORMATION: · State of Alaska w~ Blanket S,~rety~,d/orNo. Federal Insurance Co. 80391192 Amour~t $100,000.00 15. DISTANCE FROM PROF©SED * 2575 ' North LOCATION TO NEAREST PROPERTY OR LEASE LINE, FT. ofADL,,34630 (Also to nearest drig, unit, if any) 18. DISTANCE FROM PROPOSED LOCATION 'fO NEAREST WELL DRILLING, COMPLETED, OR APPLIED FOR, FT. 625' NW of Niakuk #2 21. ELEVATIONS (Show whether DF, RT, CR, etc.) EST. KBE=28' AMSL .' 23. No. OF ACRES IN LEASE 2560 PROPOSED DE~rH 2,550'MD (10,100'TVD) PROPOSED CASING AND CEbfENTING PROGRAM 17. :NO,ACRES ASSIGNED TO Tills WELL 6~0 '20. ROTARY OR CABI,I£ TOOLS .Rotary 22. APPROX. DATEWORKWILLSTAICf December 15, 1976 SIZE OF ttOLE SIZE OF CASING WEIGHT PER FOOT GRADE SliTTING DEPTtI Quantity of cement 8-1/2" 13-3/8" ----- 72# N-80 ...... 2,714'MD · 4200 cu. ft. ~--T/4], .... 9-5fg" 47# 5~°~85 10,997'MD 2800 CU. ft. _1/'2" 7" 29# N-80 12,550-fMD· 475 cu. ft': 3-3/8______" & 9-5/8'; ....... cas:rog_has already 'been cemented" in Niakulc #2 8-11 We propose to re-enter Niakuk #2 approximately DeCember 15, 1976, for the purpose of sidetracking the well and drilling Niakuk #2-A as per the attached program outline. The we]_l will be sidetracked at 10,000'b~) (8500' TVD) and drilled to a total depth of 1.2,550' ND (10,100' TVD) located 2575' NSL and 630' WEL, Sec. 23, TllN, R15E, UPM, (This space for State office use) IN ABOVE SPACE DESCRIBE PROPOSED PROGRAM: If proposal is to deepen give data on present productive zone and proposed new productive zone. If proposal is to drill or deepen directionally, give pertinent data on subsurface locations and measured and trim vcztical depths. Give blowout preventer program. 24. I hereby celtify that t}l_e Forego~'~7orrec) / SIGNED .~]~~ '51 ~'" DATE CONDITIONS OF' APPROVAL, IF ANY: OTttER REQUIREMENTS: / SAMPLfkS AND CORE CttlPS REQUIRED / MUD LO~ YES [] NO J 10 YES [] NO DIRECHONAL SURVEY REQUIRED I~ Y,'~S[] NO A.P.I. NUMERICAL CODE PEKbH.T NO. APPOVED BY 76- 79 APPROVAL DATE ~/'~~~/~'~.~~-~~~ ~r~)~ Chairman ucti Reverse Side Man. a~r Operations TITI,E ,c ~: : .:' · ., PATE December 23, 50-029-20180-01 ~.~ ~ December 23, 19f6'" Niakuk No. 2-A ~~m Outline 511 1. Rig up 13~ 5000 psi BOPE consisting of an annular preventer, two pipe rams, and blind rams. 2. Drill out cement in 13~" casing, 13-~" retainer at 2100', and dress 9~" PBR at 2108'. (]15', 3. Run ~ 47~ N-80 Buttress casing tieback string to surface and stab as,, . &~-" by 13~" annulus. into ~§ PBR at 2108' Place Arctic-Pack in ~ 4. Mill 50-ft. window in 9-~" casing at 10,000'.~· M.D. Spot 100 cu. ft. Class "G" plug across window and sidetrack well at 10,000'-+. 5. Directionally drill and core (as required) to 12,550'+ (10,100' TVD). Run multishot survey and open hole logs. 6. Run 7" 29/~ N-80 Buttress casing to 12,550'+ MD and hang as a liner at 9500'+ MD. Cement with 475 cu. ft. Class "G" cement. 7. Run 5000'+ of 7" 23~ Soo-95 A/B modified Buttress casing and hang as a circulating string. 8. Run 2-7/8" 6.4~ N-80 Seal-Lock tubing equipped with production packer. 9. Install Xmas tree, perforate, and perform flow testing as required. 10. At suspension, non-freezing fluids will be left through the permafrost zone. 22 II II t I 34 p~uD~O~ . , I0?/ I 1 1 PROPOSED ~ ~_~BOTTOM HOLE I I IIIIIII 3O I AS-STAKED I I ~ ~ NIAKUK No,2A I ' · w 0 ' ' 29 , 28 I ¢i¢~-,~ LAT. = 70 21,46.00', , , I ~¢[, ~(:{] LONG.=,~8° ,,,. ~2.64' I I b/ I X = 715,986 I I -- - i -- 1 I I Ei2N. CERTIFICATE OF SURVEYOR I hereby certify that lam properly registered and licensed to practice land surveying in the State of Alaska and that this plat represents a location survey made ,by me or under my supervision, and that all dimensions and other details are correct. Date SURVEYOR BP ALASKA INC. P.O. BOX 4-1379 31 I ! - C - STREET ANCHORAGE. ALASKA 99503 TELEPHONE (907) 279-0~44 October 18, 1976 State of Alaska Department of Natural Resources Division of Lands 323 East Fourth Avenue Anchorage, Alaska 99501 Attention: Ms. Ethel H. Nelson Acting Chief, Minerals Section Re: Proposed Exploratory Operations, Prudhoe Bay Area, Niakuk Well J~2A (23A-12-15) Oil and Gas Lease ADL 34625 Dear Ms. Nelson: BP Alaska Inc., as operator for Standard Oil Company of Ohio intends to drill an exploratory well on the referenced lease during the 1976- 77 drilling season. The well will utilize the upper part of the well, Niakuk J/2, drilled during the 75-76 season, and will be sidetracked from that well bore to a new bottom hole location within the same lease. The surface location is on the northernmost of the Niakuk Islands, 4.2 miles from the Arco East Dock in Prudhoe Bay. The attached materials (five copies) are submitted in support of this application for a permit to conduct surface operations on these lands in connection with the drilling of the well. The following are included: 1) Proposed development plan with exhibits attached 2) Area Map, Beechey Point B3-SE, scale 1:24,000 3) Well location and ice road map f/A84D-B-2 4) Site plan and rig placement drawing f~A75D-W-119 5) Spill Prevention Control and Countermeasure Plan The rig will be moved onto the existing pad on the Niakuk Island in late November, weather conditions and sea~..ice, thi~knes-s pe~mitting. . ..~"~ i,~~ ii..~ ii' ~ ~ 'i i~,, Ms. Ethel H. Nelson Page 2 October 18, 1976 Our application ~for a Permit to Drill to the State Division of Oil and' Gas will be submitted shortlY. However, the attachments fully cover the proposed surface operations. The above referred to lease at the time of issuance was made subject to wildlife stipulations. A copy of these stipulations is included he rewi th. In response to Wildlifg Stipulation paragraph (2) please be advised that Mr. R. B. Vickery, Drilling Superintendent, BP Alaska Inc., P. O. Box 4-1379, Anchorage, Alaska 99509, telephone number- office 907-265-7325, home - 907-349-5191, is hereby appointed the local agent of BP Alaska Inc. upon whom may be served written orders or notices respecting matters contained in the Wildlife Stipulation attached to the referenced lease. In addition, one of two repre- sentatives of the Company will be on site at all times; their names are Jack Barr and Paul White and they may be reached via the BP North Slope Operations Center, 659-3101. The enclosed Development Plan satisfie~ stipulation paragraph (3) while paragraph (13) of the Development Plan satisfies, we believe, stipulation (4). We would request our application be acted upon as soon as possible to allow necessary preparatory arrangements to proceed. Very truly yours, Herman A. S chmidt District Landman HAS / dw At t achment s 1:)2-~01B STATE Scott Grundy - ADF&G TO: ~ Hoyle Hamilton'- DOG Doug ~ - DEC Bill Copeland- A~/~D FROM: Pedro Denton Chief, ~tuerals Section DATE : SUBJECT: Attached for your review and cc~z~nt is a copy of the referenced lease operations. Your timely response is appreciated. SPILL 'PREVENTION ODNTNDL AND ~URE PLAN (SPCC PLAN) NIAKL~ NO. 2A T~T, SITE SPTT,T. PREVENTION CONTROL AND COUNTERMEASURE PLAN (SPCC PLAN) NIAkTIK NO. 2A W~T.T, SITE ~ATIONSHIP WITH OTHER SPCC PLANS Niakuk Well 2A is to be drilled utilizing Parker Drilling Company Rig Number 92.~ A spill prevention control and countermeasure plan (SPCC Plan) has been prepared covering that drilling rig and associated equipment. The material in that plan is generally applicable to any drilling site. This plan' provides additional planning material pertinent to this specific drilling site. It suppl~ts the material in the basic Rig 92 plan. MANAGEMENT APPROVAL AND MANPOWER AUTHORIZATION This plan is approved for implementation as herein described. Manpower, equipment and materials will be provided as required in accordance with this plan. G. (d~te)f Manager Operations BP Alaska Inc. Anchorage, Alaska ENGINEER' S CERTIFICATION I hereby certify that I have examined the facility, and being familiar.with the prOVisions of 40 CFR, Part 112, attest that this SPCC Plan has been prepared in accordance with good engi- neering practice. Richard V. Sh~fer ~J (date) Professional Engineer Alaska Registration No. 3640-E CONTENTS l® e w General Information 1.1 Facility Nam~ 1.2 Type of Facility 1.3 Location of Facility 1.4 Site Description 1.5 Time Period Covered by Plan 1.6 Name and Address of Operator 1.7 Responsible Officials 1.8 Potential Spills - Prediction and Control 1.9 Containment Policy Design and Operating Information 2.1 Site Drainage 2.2 Fuel Storage and Transfer Facilities 2.3 Blowout Prevention Program Equipment Contingency Plan 3.1 3.2 3.3 Response Organization Cleanup Procedures Uncontrolled Flow from the Well TABLES, FIGURES AND APPENDICES TABLES 1.1 3.1 Potential Spills, Prediction and Control Agencies to be Notified in the Event of a Spill FIGURES 1.1 Area Map of Naikuk No. 2A Location 3.1 Oil Spill Cleanup Scheme APPENDICES ne Be Drawing No. A75D-W-119, Gravel Placement and Rig Placement Site Plan, Niakuk Well 2A Drilling Rig Fuel Systems: Diagrams and Operating Instructions 1.1 1.2 1.3 1.4 SPILL PREVENTION CONTROL AND COUNTEP/~EASURE PLAN 1. GENERAL INFORMATION Facility Name Prudhoe Bay Area Niakuk No. 2A. Type of Facilit~ Exploratory well drilling site. Location of Facility This site is on an island near Heald Point, east of Prudhoe Bay on the Arctic coast of Alaska at coordinates X = 715,986 ft., Y = 5,985,380 ft. Alaska State Plane Coordinate System Zone 4. It is in the south- east quarter of Section 26, Township 12N, Range 15E, Umiat M~ridian, being 1726 ft. from the south line and 1130 ft. from the east line of said Section 26. ~igure 1.1 is a plat showing its location. Site Description The site on which the drilling pad will be constructed is a natural island with an elevation of approximatelY 7 ft. above sea level near Prudhoe Bay. The surface is sparsely vegetated silty sand essentially free of pattened ground and other features associated with ice w~dges. All facilities, other than the support camp, access ice roads, temporary ice berms constructed for secondary spill containment, and certain tankage vehicle parking areas will be located on the pad work area as shown on Appendix A (Drawing No. A75D, W-119). The suppo~rt camp will be located on another island just to the south. Under normal conditions the well site can be reached from the Prudhoe Bay road system after a ten minute drive from the ARCO dock. -1- ,[ 22 27 PROPOSED ~O_.~BOTTOM HOL SIAK~K No.,2~ LAI = 70°21 46.00" LONG. =148° 14'42.64" X = 715,986 _L 34 32 33 I I pRuDHOE' ! ,,,/~, .... D./L .... /---1-: q S''// .... "'< SCALE I"= I MILE CERTIFICATE OF SURVEYOR I here'by certify that I am properly registered and licensed to practice land surveying in the State of Alaska and that this plat represents a location survey made by me or under my supervision,, and that oil dimensions and other details are correct. -/0- 7.5 Date REVtSED(PROc-OSED) BOTTOM HOLE~ NIAKUI~, ~.t~ '~A ADDED (PROPOSED) BOTTOM HOLE page 2 SURVEYOR SEPT 1,1976 M GAG OCT 15,1975 C J P AS- STAKED NIAKUK No. 2A Located In SE I/4 PROTRACTED SEC 2~,~ T 12 N, R 15 E iUMIAT MERIDIAN SUrveyed for B.P. ALASKA INC. Surveyed by F. M. LINDSEY I~ ASSOC. LAND ~ HYDROGRAPHIC SURVEYORS 2502 West Northern Lights Boulevard Box 4-O81 Anchorage Fig. 1.1 Alaska 1.5 1.6 1.7 Time Period COvered by Plan Work will cc~m~nce at the site as soon as the sea ice is strong enough to support heavy equipment--probably in December, 1976. It is expected . that the drilling rig will be released in February 1977. Name and Address ?.f 0perator ~ The 'operator for this exploratory well drilling operation is: BP Alaska Inc. 3111 "C" Street P. O. Box 4-1379 Anchorage, Alaska 99509 ~Responsibl.e' Officials The following individual is responsible for the planning and coor- dination of pollution control efforts: RiChard V. Shafer, Envir~tal Engineer BP Alaska Inc. P. O. Box 4-1379 Anchorage, Alaska 99509 Office: 265'7452 Hom~: 274-3149 When the rig is on location at the drilling site, the ~rillin~. Super- visor has full authority and responsibility for all activity at the site, including pollution COntrol work. In the event of a spill the .Drilling Supervisor may request assistance frcm one of the follow- ing two individuals who can always be reached through the BP Operations Center, Prudhoe Bay Oilfield: Charles H. Wark N.A. "Slim" Gilchrist -Field Coordinator Deputy Field Coordinator Ext. 211 Ext. 211 1.8 Potential Spills - Prediction and Control Table 1.1 lists, a number of oil spill circumstances that might occur during the .drilling of this well. It should be recognized that pre- diction of quanti~ies and details pertaining to potential spill events is very difficult to do with any precision. Indeed, 'the very low spill rate that has been experienced during BP drilling operations~ in Alaska has provided little statistical basis for future projections. The quantities listed in Table 1.1 should be considered only as very approximate estimates of the order of magnitude of the largest spill event in each category which might'be reasonably conceived. MAJOR TYPE QUANTITY SPILL RATE SECONDARY SO3RCE OF FAI~ LYRE (bbls) (bbl/hr) CONTAINMENT Fuel Tank' rupture 200 - None delivery vehicle Broken hose 75 300 Fuel Tank Tank rupture 595 - Gravel or snow ........ berm, sealed Overflow 75 300 with ice Fuel trans- Line rupture 100 50 None fer line , , , Well Uncontrolled 300,000 3,000 None flow of crude oil or wellbore fluid i i i11 i 111 i 111 il 11 , , , i , _ Table '1.1 Potential Spills - Prediction and Control 1.9 Containment Policy Containment structures are' practical for the fixed fuel storage facilities at this drilling site, and they will be provided. Plans showing construction details for the pad and containment berms are included as Appendix A to this plan. -4- 2.1 2.2 2.3 2 .' DESIGN AND OPERATING INFORMATION Site Drainage The drill site pad surface and w~rk area will have a minimum elevation of five feet above the surrounding terrain with 1.5 to 1 side slopes. Facilities located ~n the pad surface which might spill oil shall be surrounded by berms of ice and snow or gravel. A reinforced plastic membrane will be placed beneath the entire drilling rig structure. The membrane and the pad surface will both slope into a welded steel cellar which will be permanently attached and sealed to the conductor pipe. Any oil or other contaminant which leaks or is spilled frcm drilling rig equipment will drain into the cellar frcm which it can be subsequently pUmped and transported to an on-shore disposal pit. Fuel Storage 'and Transfer Facilities As shown on Appendix A, fuel will be stored in steel tanks which will be surrounded by a snow and ice or gravel berm system constructed for secondary containment. Once the berm is constructed it will be sprayed with water which when frozen will form an ice barrier. Fuel flow diagrams and transfer procedures are included in Appendix C. All personnel working in the fuel handling area will be thoroughly trained in these procedures. Blowout Prevention Pr~. ram ...E~ui~t This rig will be equipped with a 20" 2000 psi W.P. annular diverter system installed on 80' of 20" H-40 94# conductor pipe while drilling 17-1/2" surface hole to 2700 ft. In the unlikely event that low pressure, low volume surface gas is encountered, the wellbore fluid can be diverted into storage and the gas allowed to vent to the -5- atmosphere. After running and cementing 13-3/8" 72# N-80 surface casing at 2700 ft., a blc~out preventer (ROPE) consisting of three 13-5/8" 5000 psi W.P. rams, a 13-5/8" 5000 psi W.P. annular preventer, and a two-choke rm~aifold will be installed. These preventers are pc~ered by an accumulator system with beth nitrogen and manual back- up. After installation of the BOPE, it will be thoroughly tested for leaks us'.zng diesel fuel. It will be tested at least weekly thereafter, as well as prior to drilling out casing shoes. Operational bests and crew drills will be conducted daily. Primary .well control will be maintained by over-balancing formation pressure with a column of drilling fluid. Autcmatic and manual moni- toring equipment will be installed to detect any abnormal variation in the mud system and drilling parameters. A mud logging unit manned by~ experienced personnel will be in continuous use while drilling intervals where hydrocarbons are susPected and will monitor formation pressures, hydrocarbon shows, and loss or gain in the mud storage reservoirs. In the event that the ~1t kicks, the BOPE will be used to shut in the well intnediately and confine the pressure within a closed system. The casing program is 'designed so any anticipated formation pressures can be shut in at the surface withOut breaking dcwn the casing shoe. Pressure resulting frc~ a kick will be circulated out using the balanced bottcm hole pressure method and the well will be restored to its normal operating condition. These personnel will be further supported by well-trained drilling crews approved by the Company. A description of the Company's current blowout prevention training program together with a copy of its "Drilling Operations Blowout Prevention Manual" is available for inspection by appoin~t. Company representatives assigned to the , drill site receiVe extensive training in well control. 3. CONTINGENCY PLAN 3.1 Re_sponse Organization The Drilling Supervisor shall take charge at the scene of an oil spill near the rig, and shall notify the Field Coordinator, or in his absence the Deputy Field Coordinator, without delay. The Field , Coordinator/Deputy Field Coordinator shall provide oil cleanup assis- tance to the Drilling Supervisor utilizing rig-assigned personnel or bringing in additional personnel as required. He shall also notify the .Environmental Engineer without delay, in accordance with BP Alaska Inc. Standing Instruction #3~76.. The Environmental Engineer shall notify appropriate regulatory agencies as listed in Table 3.1 and shall arrange for special cleanup equipment or outside spill cleanup teams as required by the circumstances. Table 3.1 Agencies to be Notified in the Event of a Spill NAME OF CIRCU~.~TANCE RE_QUIRING AGENCY CONTACT PHONE NO. REPORT Environmental Pay ~rris 265-4881 Any spill which might reach navig- Protection able waters (generally any surface Agency, water) in harmful quantities (An Anchorage oil "sheen" is considered harmful) U. S. Coast 265-5371 Any spill which might reach navig- Guard, able waters in harmful qsk~ntities Anchorage Alaska State Doug Lowrey 452-1714 Any spill on state land or waters 'Department of of the state Environmental Conservation, Fairbanks 3.2 3.3 Cleanup ~Prpcedures Figure 3.1 shows in schematic form the various operations which might be involved in cleaning up any particular'oil spill at this well site. The notes accc~pahying Figure 3.1 provide explanation and amplification of the diagram. Uncontrolled Flow from the Well As a matter of policy, BP Alaska strives for the best and safest engineering techniques in well drilling, completion and w~rkover. Because of this policy, uncontrolled flow from any well is extremely unlikely; hcwever the possibility of sc~e catastrophic event producing a blOWout must be considered, and a plan has been made of the action required to m~et such a contingency. A copy of this plan is available for review by appointment. -8- 3C°nstruct snow berm as required. Yes Protect lives~ propeP ty~ etc. 5 Attempt shutoff at surface. Drill relief Well. Yes Kill well. up spil led oil. ~o Transport oil to burn pit. Burn. 12 After break- up rig booms and skim. FIGURE 3.1 OIL SPILL CLEANUP SCHEME No Crude oil Stop spill 20 Bui Id sump and drain system, Skim. -Sorb. 14Clean gearI inventory re- order. 15 Critique. Restoration No END ~ Needs more work -9- NOTES PERTAINING TO UNIT OPERATIONS AS SHOWN ON OIL SPILL CIY_ANIIP SCHEDULE l. . . e . . 7. Spil.1' event. A spill event is any spillage of crude oil, product, or other harmful liquid under circumstances such that the workpad fill material or the surrounding area could become contaminated. Included would be such events as fuel loss through a broken hose, an overflc~ of oil contaminated mud during a well kick, or fuel overflow during tank filling. Not considered a spill event are any small spill beneath the rig or into the cellar, provided the spill is completely contained by the oil-proof membrane and none is permitted to seep into the pad. Protect.!iv.es, pr.operty,.._.etc.. Take ~iate action as required to prevent fire and to protect personnel, property and wildlife. 'ConStruct snow berm a.s. required. The spread of spilled oil can be restricted by construction of snow berms. The snow berm should encompass sufficient surface area to acconmodate the expected spill volume. Distillates will flow beneath the snow, so the area should be surveyed by testing snow samples with an infrared spectrophotometer, or by testing the air near the surface with a gas chrcmatograph. Either of these methods should indicate the presence of hydrocarbons beneath the snow. The surface of the snow berm should be made impervious by spraying with water. Uncontrolled well. ,Conservative practices employed by BP Alaska Inc. make loss of well control highly unlikely. Key features of the blowout prevention program include: well engineered casing and cementing systems to prevent migration of fluids outside of the wellbore, good mud control to prevent well kicks or lost circulation, well engineered and properly maintained blowout prevention equipment to control unexpected flows of fluid to the surface, and a well operated training program, including hands-on exercises, to ensure that men and equipment do the right thing at the right time. Attent0t .s.hutoff. a.t s.urfac?. Most uncontrolled wells are brought back under control by operations at the surface.. Specific actions depend on the configuration of the wellhead at the time. Actions which might be applied include pumping weighted mud and lost-circulation material into the kill line', application of dry ice to the wellhead to freeze off the flow, and use of specialized (Red Adair) equipment. Drill relief well. It is e~ted that BP Alaska will have at least three other drill'ing rigs under contract at the time of drilling this well. Drilling sites and procedures will be determ/ned based on specific conditions requiring a relief well. Kill well. Killing the flow from an uncontrolled well requires the injection of large quantities of fluid into the formation. Water for the well killing fluid will be obtained from the ocean. Pipes for delivery of the water should be insulated with snow to prevent freezing. . 10. 11. 12. 13. 14. 15. 16. 17. 18. Scrape up spilled oil. At the ambient temperatures at wintertime in the Prudhoe Bay area, crude oil will be highly viscous, and not readily pumped in small diameter lines. The spilled oil should be picked up with earthmoving equipment (scrapers, front end loaders) for transport to an area where the oil can be safely burned. Addition of snow to the oil, as a sorbent, will probably improve the handling characteristics. Mixing of snow and oil can be done with bulldozers. Transport oil to burn pit. Oil can be transported to an approved burn pit by use of dump t~u~ks or scrapers. If dump trucks are used their beds should be lined to minimize loss of oil enroute. Burn. After the oil has been delivered to the approved burn pit it shall be ignited. Use of more than one burn pit will permit continuous cleanup operation without the accumulation of large quantities of unburned oil in a burn pit. After breakup rig booms and skim. At the tim~ of breakup, a floating boc~ should be rigged encc~passing the entire area affected by the spill. Initially, this boc~ can be placed in trenched lines or natural breaks in the ice. Skis and Oil Mop equipment shall be used to pick up any concentrations of oil in the area. Sorb. After the bulk of the spill has been picked up, final cleanup can be accomplished with sorbents such as 3-M Brand Oil Sorbent. Clean Gear, Inventory, Reorder. If this step is not carried out, materials will be consumed, equipment will beccme lost or unusable, and the "next spill" cannot then be properly taken care of. Critique. After the spill is cleaned up, but while memories of it are still fresh, those involved in the spill should sit dc~a~ and discuss what went Wrong (and what went right) during the operation, hc~ things could be improved, and how better preparations could be made for future spills. An informal report should be made of the critique. Monitor. Periodically after the cleanup the site should be inspected, photographed, and surveyed for contaminants. In the case of winter spills, it may be necessary to take additional cleanup action at the time of spring breakup. The inspections may reveal the necessity to do certain rehabilitation.work such as revegetation to avoid degradation of the site. O.K. For One Season? If the affected site has been stable for one year and shows signs that damaged vegetation is becoming restored, action on the case~ may be .terminated. Stop spill. Shut off valves, transfer fuel frc~n leaking vessels, repair leaks, take other appropriate action to prevent spill extent frc~ growing. What Oil? As shown on the diagram, different action is required for crude oil spills than for spills of distilled products. 19. 20. Build sum~ and drain system. Natural drainage can be augmented with collection channels leading to a sump dug in the ice near the pad or in the pad itself, depending on how far the oil has spread. Skim. Oil collecting in the sumps can be removed using pumps, skinm~rs or Oil Mop equipment. -12- DRILLING RIG DIESEL SYSTEM M -8A 25,000 GAL.. DIESEL STORAGE M -2A M-SE 25,000 GAL. DIESEL STORAGE M-2B M-SC 25,000 GAL. DIESEL STORAGE M-2C INLET M-4 FUEL TRANSFER HOUSE _1 CONTAINMENT BERM M-5 VEHICLE REFUELING -9 ' TOP FILL RIG DAY TANK M-7 lToP FILL GENERATOR t TANK /2o3o G~L / DIESEL 1 TO GENERATORS DRILLING RIG BOILERS, GEN'S, MOTORS AND I HEATERS. I i I ..,..._ .. _J DRILLING RIG DIESEL SYSTEM Notes: ,,, All valves to remain closed except where operation of system requires they be open. 0 Valve tagged M-8 on diesel storage tank must remain locked closed at all times. Filling Storage Tank 'Fe · A. Check level of tank to detenmine required volume. B. Connect tanker hose to inlet. C. Open valve taggedM-2 (close to tank). D. Open valve tagged M-1 at inlet. E. start pumpon fuel tanker and fill tank. Stop pump when tanker'is empty or required volume is in tank. G. ,Close valve tagged M-2. H. Start tanker pump withreverse flow to remove liquid in piping and transfer hose. I. Close valve tagged M-1. J. Stop tanker pumpand disconnect hose. Transferring Fuel To Day Tank A. Check level of day. tank to determine required volume. B. Check that valves tagged M-1 and M-9 are closed. C. Open valves tagged M-2, M-3, M-4 and M-5. D. Depending on tank to be filled, open valve tagged M-7 or M-6 and check that valve tagged M-6 or M-7 is closed. E. Start transfer pump and transfer fuel through fuel meter until required volume hasbeenpumped. F. Stop transfer pump and close valves tagged M-7 or M-6' G. Close valves ~2, M-3, M-4 and M-5. Check accuracy of fuel meter frequently by cc~paring actual volume of fuel pumped withmeter reading. B-2 CONTAINMENT BERM TOP FILL I000 GAL. GASOL I N E SERVICE STATION TYPE VALVE DRILLING RIG GASOLINE SYSTEM DRILLING RIG GASOLINE SYSTEM Notes: All valves to remain closed except where operation of system requires they be open. Filling A. Check, level of tank to determine required volume. B. Check that valve tagged N-1 is closed. C. Fill tank using tanker hose, taking care not to overfill or spill fuel when removing those. Transferring Fuel A. Open valve tagged N-1. B. Fill vehiCle using service station type valve taking care not to spill any fuel. Close valve tagged N-1. Ce B-4 CHECK LIST FOR NEW WELL PERMITS Company ~ Yes No Remarks .1. Is the permit fee attached - _ -. 2,:- Is well to be located in a defined pool ................. /~ o,. Lease & Well No. 3. Is a registered survey .plat &ttached ................ ~-, 4. Is well located proper distance from property line .......... ~ 5. Is well located proper distance from other wells ........... 6. Is sufficient undedicated acreage available in this pool ....... ~_ 7.. Is we'll to be deviated ........................ /,~K_ 8. I,s ope~ator the only affected party ................. ~ 9~ Can permit be approved before ten-day wait ? ............ ~ ~.lO. Does ~perator have a bond in force .................. ~ l l. Is a conser, vation order needed .................... ~ 12. Is' administrative approval needed .................. ~? 13. Is conductor strifig provided . .................. ~ ~ 14. Is enough ~cement used to circulate on conductor and surface ..... i.. ~. Will cement tie in surface and intermediate or production strings . . Will cement cover all known productive horizons ........... Will surface casing protect fresh water zones ............ 18. .Will all casing give adequate safety in collapse, tension & burst 19. Does BOPE have sufficient presS~r~ rati~n~q ~¢~.~ .~~-.C~.. ~-.o~?p.~. ~" li:~cional Requirements'~-~ Approval G'eo 1 o,Qy TRM JAL Recommended' Engineerinq' HWK ~/~< OKG , HHH Lcs