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STATE PIPELINE COORDIN-~kTOR'S OFFICE g Department of Environmental Ccaservation - Deoartment of Natural Resources _- Department of Fish and Game TONY KNOWLES. GOVERNOR ::' ',*/ES- 4'~ AVENUE. SUITE 2C :NCHOaAGE. A,_ASKA 99501 :~ONE..977t 275-8594 · 7-~71 278-8595 =aX '907' £'2-6690 January ~2. : 995 Letter No: 94-08-DRT File No' 300.15.202 CERTIFIED MAIL P,_ETURN RECEIPT REQUESTED - 023 '98 397 \fr. < ......,m Tar[or BP Exploration ~A!aska) Inc. P. O. Box ~96612 Ancnora2e..-~ 995~ 9-6612 Dear .",Ir. Taylor' Re: BP Exmoration ~Alaska/ inc :'' ~;'"~ ' .... ac .... Dfiiiin~ Waste Disposal Facii~t'.' Closures - Numerous inactive Sires The Alaska Department of Enviroramental Conservation tADEC) has received and completed its review of,,'our Auaust 9. ~993 ',~,:~- with enclosures. "~ e ' _ _ , ........ ~u sun_~ approval for closure of BP Exsioration {,Alaska} Inc. Drilling Waste Disposal Facilities on the Norm Slope. These sites have been reviewed in accordance with the ADEC Interim Site .Assessment Guidance for Inactive Drilling Waste Sites. June i991. This correspondence describes our review 2rocedures. puts forward the devartment's findings, and takes action on the r:auests. Currendv. nhe second draft of Alaska's new Solid Waste Re_o-uiations. i S.AAC 60. are under review, and this second draft contains a chapter on inactive Rese,,we Pit closures. The closure criteria in th/s proposed re_m.tiation parallels the closure criteria in the 1991 Guidance Document. Closure under the !99! Guidance Document should constitute ciosure under the proposed Solid Waste Re=re.clarions if they are adopted as current drafted. The Review Procedure The cmaiitative 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 ~enerator. A decision scheme is then emr)ioved to establish ~1'; whether or not there is a Mr. Steven D. Taylor January 12. 1995 BPXA Inactive Drillin_o Waste Disr~osai Faciiitv Closure Approval basis of concern, and ('2') whether e" not a waste site ~s iikeiv to present slgmficant risk to human or environmental receptors. The first step in this screening criteria is establishing a basis of concern: "If the waste site has released contaminants or there are mechanism for potential reieases and there are receptors nearbv, then. there ma,,' 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 rezer~tors nearby, then there is not a basis for concern and the waste site should be consiciered ~:oseci." ,. ne -rlterla that ai-e measured at a waste site to satisfy ~';=~,,,. above lo_oical ar2uments are' Evidence of reiease of chemical contamination a: the waste site in excess of Alaska Water Quaiity Standards rot ,_n,. or more .~, _o~,~ -omr)ounds. or Mechanism for potenuai release, and Proximitx' of the waste site to biological receators. 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 shall identify alternative wavs to correct or miti=ate the basis of concern, r~revent its recurrence, and select a preferred approach. Corrective action alternatives shall be described at a conceatual level, and the selection ora preferreci approach shall be based on balancing protectiveness with imr>lementabiiitv 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 "neglio_ible." The finding or-----_s_ignificant risk is based on the likelihood of exposure and the likelihood 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 uniikel',.' or the conseauences of exposure are not 'adverse.' then the risk is negligible. *Ir. S-re;'en D. Tavior January '2. 1995 BPXA inactive Driii;'-~,,.._ Waste Dissosai Faciiitv Closure Armrovai If risk at a waste site is si~pdiciant, thencorre,.t," 4"~,~ a:.uon should be taken. The criteria that are evaluated at a waste site to satisfy -b,~, ,. iohicai .., ..... =~,,,,,,.~¢ above are ~-~,,~~.,~,~ criteria and comeauence ~-;, ~ Exposure Criteria: Recestor exposure is considered to be iikely when: Contaminant r:iease mechanisms,~.,.~,~ :ud=ed _<!znificant . er Contaimr~ent ,m'~ration is iud~ed si~mficant. -- One or more contaminants are ~.n,,lror.m .... A.x persistent. If exsosure is founci to be urdikeiv, a finding of nehii_oibie risk is made on the basis of absence of a iikeiv exposure item and the action 2ian is evaluated under t~e tint, act/Benefit Evaluation stea. The =urnose of this ste~ is to dete.n-nine whether the benefits of taking, a corrective action would be greater than the impacts or' taking such a corrective action. If any one of the exposure criteria are met. a finding is made that exposure is likely. screening then continues to evaluate Consesuence Cmeria. Further Consequence Criteria: Adverse consequences of exsosure to contaminants from reserve pits are considered to be likely when: {al The ' ,r- ri · ama_on or freauencv of exposure is suffic:ent to cause adverse health and environmental effects. This is evaluated by reviewing human and wildlife use patterns at a given waste site. waste site accessibility, and ground and surface v,'ater uses. and either; (b) The quantits' or concentration of one or more contaminants exceeds sertinent 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 taruet contaminant, to identify exceedances. When only human populations are at risk. health criteria are used. When orfly populations at risk are nonhuman te.g., fish. wildlife, vegetations, environmental criteria and standards are used. or: (c) One or more contaminants exhibit hi_.h acute toxicitY. The NIOSH toxicity ratm~ system /NIOSH 1974; ,.,,.'iii be used to identify contaminants highly toxic to mammals. This .',,'Ir. Steven D. Taylor Janua~' 12. 1995 BPXA Inactive Drilling Waste Disposal Faciiitv Closure A. pproval information will be used to dete,,rmine whether a'~ar_eto comsound exhibits acute hith toxicitv. If the duration and freauencv of exposure is insufficient to cause adverse effects, there is no need to evaiuate the other two conseauence criteria, and a findina of ne21i.~ible risk is made. If the duration and frequency term is sufficient, but neither of the other two consequence criteria are met. a finding of negiigible risk is made. The action plan is then evaluated under the Impact/Benefit Evaluation stev. If the duration and freauencv of exposure is dete.,'anined to be sufficient to cause adverse effects anti eib, er of the other tv,'o conseauence criteria are satisfied, then a findint is made that adverse consequences are iikeiv, and the risk at a waste site is sa~d to be si_onificant. If the s,.,,.~.mn_ indicates that risk is significant, then the responsible part5.' shall p. roceed v,'ith impiementations of COrT,.~.t,X e actions. SITES CONSIDERED FOR CLOSURE Based upon the above rsferenced criteria from the June 1991 I2',,'TER~/I SITE ASSESSMENT GU'IDANCE FOR LN'ACTD,:'E DRILLLNG WASTE SITES. the following sites listed below have been reviewed for closure' ARCTIC FOOTHILLS SITES WEST SAK SITES Shale Wall Unit #1 b3-oz..s~ West Sak 4 Kemik Unit ~! 9o- Kemik Unit .-.-'2 ~q' 03'5 Kuparuk Unit 1 & lA 8'~. o~,8'~, o~4 T Gubic Unit #1 Itkillik Unit No. 1 ~'+-=~5- Finn Creek Unit 1 PUT RIVER SITES Put River 17 10-14. 14-10-14 Put River '' _?-10-!4 6~- COLVILLE DELTA SITES Nechelik Unit #1 81-i~q SAG DELTA AREA Sa~, Delta Unit No. 1 t,a- o{,~r Sa~ Delta Unit No. 2 10-11-16 74,-ogl 7 Sa~ Delta Unit No. 11 84- ~, 2_. OFFSHORE ISLANDS IN ALASKAN WATERS Alaska Island ,.1 ~l*llet Niakuk 4. -. 6 s4-zo¢,~ e,s'.oz"4 , Challenge Island #1 8o-oqo Lon~ Island #1 8a.}{,'~ Niakuk 1. IA. 2. 2A Niakuk 3 '~8-o~'+ :/'t--ot.~-/ ':}(:,-oz8, "J,-s"-o~3, :/-.t.' o'k~} (SS"-2.':/,& _',Ir. Steven D. Tavior lanuar,' il. !995 BPXA inactive Drilling Waste Disoosai Faciiitv Closure Approval The Cecision to grant closure approval on these ~.ites has been based ", on a review of the submitted ' ,-,i,.,~ 'to ' ~na,. .... driilin~ waste assessment documents iisted below bx' the ADEC-PCRO Solid Waste. Water Quail.rT. and Contaminated Site S'~':~ and i2'~ " site , isits bx' PCRO staff durin2 luiv of iQ93 aion~-with the resuitant ~o~, ~, '~' . .. r,.,.,_.ma-ne,,e,.a remedia[ actions by ADEC ,nd,.,~aK,-n at a certain number o~ theseb,,.s.-;~'= Title' Inactive Reserve Pit Protram. Assessment and Closure Supporting Documents: BPXA Video-documea,tation of Pit Ciosure,'Site Restoration Comuarauve Anaivsis of $oii & Water Samaies Submittina Person' -- Covered Facilities: Dave howe. BP E.'.:oiorat:on ,.Alaska; Synopsis of Closure Procedure: Closed as is. No mniner action is needed for the drillina waste facilities at these sites, except as noted beiow. CLOSURE APPROVALS · '~-~"~' ' the The Des~ru'nent s ~,,.~on uson rssuest for closure application submitted by BP Exnioration /Alaska} Inc. is to sssrove for the below listed drillin£ waste facilities sites. effective lanuarz' il. 199S. Uson review or' the submntted samnie results resuireO under the 1991 Guidance. zsxain remote sites exnibimd metal concentrations and hydrocarbons in the reserve put surface waters and down}r,~dient waters in excess of the Alaska Drinking Water Standards and Alaska Water Quality Criteria i AWQC'i. While there i~ a basis for concern for those sites where exceedances occurred, there is aisc ne~ible risk. and an;' corrective action warranted at these remote sites would not be resuired. ~ ' ~ ~ ,~,altz.n_ that the imnact of the corrective action would be much ~reater than the benefits received, lh~se sites~for the most ., part have reve~¢tamd, and any corrective action measures implemented woulddmpact the established plant species a~ these sites. Itese sites are Closed As Is. Itere are certain sites where con'estive action is wan'anted, however, and Conditional Closure is ~ranted. provided the corrective action stipulations described are completed to the denartment's satisfaction. .Xlr. Steven D. Tavlor January i2, 1995 BPXA Inactive Drilling Waste Disr~osal Facilitw' Closure ,Approval CLOSED AS IS Nechelik Unit #1 - . Sag Delta 11 -~ Alaska Island #1 ' Niakuk 4. 5, 6 - Challenge Island gl · Long Island #1 ~ Niakuk 1. iA. 2, 2A j' 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 - Gubic Unit #1 CONq)ITIONALLY 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. Shalde Wall Unit gl Remove unused drilling additives and pallets. Kemik Unit gl Stabilize any exposed drilling waste in reserve pit Fertilize. plus seed and/or transplant with commercial or indigenous plant material Kuparuk Unit 1 & IA Stabilize an,,' exposed drilling waste in reserve pit Surface preparation of site needed (scarifs.'. add soil amendments, fertilize l Monitor site using aerial photography *Ir. 5revert D. Tavior Janua~' i2. i. 995 .-3PXA Inactive Drilling V~'aste DisDosai Facility Closure Approval Itkillik Unit No. 1 Stabiiize an',' exposed drilling_ waste ;n reserve These conditions have been '~iaced on the below-named sites follov,'in,z_ the site '*'isit/closure package evaluation. Once these conditions have been met. these sites will be considered CLOSED' Finn Creek 1 R,,mox,. stockDiied debris Ferriiize. ~'ius seed anci,,or .'.ransviant with commercial or indigenous ¢iant material to enhance natural biode~raaation of residual hydrocarbon contamination in the soils and waters at the site Stabilize an',' " ' ~-;::;.c. .... e..Dosea .,,,.:,i,~_ waste ,~se. xe Sag Delta Unit No. i Sag Delta Unit No. 2 10-11-16 Cap existing reser,,'e pits with available g~ravel and rezontour pits to blend into surrounding te.,-rain Terms and Conditions These ciosure aDDrovaiq ~'~ subiect to me followin2 te,wns and conditions' FULL SITE CLOSURE' The approval granted b;' this letter is for the inactive drilling waste sites only. as required under 18 AAC 60.500 Id/. Closure for the pad as a whole must be coordinated between the owner:operator and the appropriate state t. ADNR. ADF&G..-XOGCC't. or federal (BLM) agency. Additionally. should an.,,' contamination from historic spills be found on the pad outside the drilling waste site I reser,,'e pit area), notification needs to be made to the ADEC.'PCRO Contaminated Sites Section {271-4399'1. Mr. Steven D. Taylor January 1"_. ~'995 BPXA Inactive Drillin~ Waste Disr>osai Facility Closure Approval NEW LNFORMATION: Should additional information concemin2 environmental conditions at the faciiitv make further actions necessar,,, to r~rotect human health or the environment, the Department reser~'es the right to recmire additional investigation, assessment, monitoring, or remediation at the faciiitv. Mr. 5revert D. Tavlor Janua~' 11. 1995 BPXA Inactive Drillino_ Waste Disr~osal Faciiitv Closure Approvai DUT'¥ TO RESPOND: Notwir2nstanding anv other provisions or reauirements of this closure a?proval, a person causing or permitting the discharge of oil or other hazardous substances is rec~uired by law to irnmediatei¥ contain and clean-ur2 the discharge. ~:XS 46.04.020: -t6.09.020). COMPLLkNCE WITH APPLICABLE LAWS' If amendments to this closure approval are necessar',' to meet the requirements of anv new laws or regulations, the faciiitv 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 an,,' questions. ~iease do not hesitate to contact Tim Law at 271-4051 of this orrlce. Sincerely. 7/// / ADEC Regional Administrator Pipeline Corridor Region ~ohn Samora. BLM/JP0 Dave Lowe, BPX Anchorage AOOA/Anchora~e Jerrv Brossia. ADNR/SPCO o Nancy Welch. ADNK."Fairbanks A10tt. ADFG,.'Fairba.nis Glenn Miller. Dour Bauer. ADEC,'Juneau ' Jim Havnes. ADNl:L'Anc,,ora2e Keith Mueller. USFYvS,,-~ncnora,e Jessie Kaleak Sr.. Mayor NSB/Barrow . . Para Miller, Tine Wiidemess Socierv,'Anchora~e -'Lan-v Lanclr,,' Nortne2 Alaska Environmental C~,,L~, Fa~r~artrs Standard Alaska Production Company 900 East Benson Boulev~.,~ P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 564-51 I 1 STANDARD ALASKA PRODUCTION September 29, 1986 State of Alaska AOGCC 3001 Porcupine Drive Anchorage, AK 99501 DATA TRANSMITTAL - Sag Delta 6 Pressure Survey - Sag Delta 11 DST Data Report - 4 volumes Please indicate receipt of this material by signing below. Please handle this material in a confidential manner. K. A. Lauder "m OCT 0 2 19BB __ei v e.~,aska Gas Cons. Commission Oil & Anchorage KAL'deh:OgO7h A uni! of the originot Ssandard Oil Compony Founded in Clevelond, Ohio. in 1870 SOHIO PETROLEUM COMPANY SAG DELTA ll DRILL STEM TESTS DATA REPORT These four volumes document the events which occurred and contain the data generated during the testing of Sag Delta ll~ There were three open-hole tests and five cased-hole tests~ This report consists of data and observations only; interpretation of results are issued separately by the Lisburne Project team~ A few notes on how this report is arranged may aid the user; The Summary of Tests section in Volume I provides an overview of each test. Key information about the interval; test sequence, and results are summarized on several pages for each test; (Actually; the first two pages provide the most important information); The remainder of Volume I provides the details about each test; Because the surface and bottomhole data printouts are so bulky, they are bound separately in Volumes II through IV; However, key pressure information for each test is included within both the summary and detailed sections of Volume I;. Finally; the appendix contains some miscellaneous information such as a list of acronyms for those who may not be conversant in tile jargon of North Slope testing; Some additional points of interest: 1; All of the tests were performed with drill pipe and test tools with the exception of the last test; DST 7A; in which tubing and a packer were used, 2; The well was a straight hole; therefore depths shown as "measured" are also true vertical; The kelly bushing was 46;2 feet above sea level, 3; Wellhead pressure data was recorded by multiple testing service personnel; Readings and circular charts are found near the end of each detailed section in Volume I (Flopetrol/Johnston data); Digital instrument printouts are included under "Surface Data" in Volumes II through IV in each DST section; Any questions or comments about this report should be addressed to M,D, Martin (Anchorage) or CjM; Michel (San Francisco)J RECEIVED OCT 0 2 )986 Alaska Oil & Gas GODS. bu~Hmissiorl Anchorage CMM/mc/1Rq~l /8 Telecopy No. (907) 276-7542 September 9, i986 M~. R. S. Allan Division Drilling Engineer Standard Alaska Production Company P. O. Box 196612 Anchorage, AK 99519-56i2 Re: Final Location Clearance Sang Delta No. 11 Permit No. 84-182 Sec. 27, T!IN, Ri6E, UP~ Dear Mr. Allan: During a meeting in our office in August, 1986, we agreed to approve final location clearance for the above referenced well after you provided us with evidence that eight breaches (two per side) had been cut in the flare pit so water could no longer be retained within the pit. By letter dated August 28, 1986 you stated that the flare pit had been breached in eight places, and photographs were provided showing the breacne~' ~. Based on the above, we hereby approve final location clearance of Sag Del ta wei~ . ~ · No il. Standard Alaska Production Compan, 900 East Benson Bou P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 564-5111 STANDARD ALASKA PRODUCTION August 28, 1986 Mr. L. C. Smith Commi ssioner Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501-31 92 Re' Location Clearance, Sag Delta #11 Dear Mr. Smith' As we previously agreed, the final location clearance for the above referenced well was completed August 24, 1986 after eight breaches (two per side) had been cut in the flare pit using a backhoe mounted on a Rolligon. The enclosed photographs illustrate the work carried out. Any subsequent snow and ice development within the fl are pit will now dissipate during each successive warm weather period. Now that the flare pit can no longer retain fluid, we hereby seek notification of acceptance of final location clearance for Sag Delta #11. Sincerely, RSA/J FG/pm/1099D Attachment CC' R. B. L. Nel H. Rei ley L. Rose M. Driskill 1 File' Sag Delta #11 R. S. Allan Division Drilling Engineer A unit of the original Standard Oil Company Founded in Cleveland, Ohio, in 1870. Final Location Clearance- Sag Delta ~1 I Flare Pit 8/24/86 Telecopy No. (907) 276-7542 July 9, 1986 Mr. R. S. Allan Standard Alaska Production Company P. O. Box 6612 Anchorage, AK 99502-0612 Re: Location Clearance Sag Delta #11 Dear Mr. Allan: A review of our records shows that final location clearance for the above referenced well has not been approved. in compliance with Section i70(a) of our regulations, "It]he location of an abandoned well onshore or upon a historically stable island must be cleared within one year following well abandonment or .... " Section 170(b) provides the means for an extension of time if a valid reason exists, and Section 170(c) provides for an on-site inspection. This location was inspected in 1985. The few boards and trash that were on the location at that time were removed at a later date. According to the field inspection report, the flare pit needs to be filled or the embankment needs to be removed. We are, therefOre, requesting a schedule from you for this sum~er when our field inspectors can accompany your representative to the well site for final location clearance inspection. S i~ cereiy ,~ ..... ,.o~;.-~e C. Smith Commissioner jo/A.HJH.6 SURFACE ABANDONMENT REPORT · 20 AAC 25~ ARTICLE 2 20 AAC 2~.120: WELL ABANDONMENT MARKER: Did Steel Post (4"Min) ~' · . __.. , Len§th (lO' 'Min.) /~Z~ tleight Above Final Grade Level (4' ~iin.) ~" ' Top of Marker Pipe Closed with: Cement Plug Screw Cap Set: On Well Head , On Cutoff Casing ~.-/_, In Concrete Plug Distance Below Final Grade Level $f ° Ft. in. Side Outlets: All Valves and Nipples Removed .~_j · Ail Openings Cl.osed ~_~, With Blinds , With Cement · INFORMATION BEADWELDEI) DIRECT~LY TO MARKER POST: ' (List Where Different from File Information) Operator Unit or Lea'se Name Well Number. , Surface Location of Well: _.-~/~ Ft. F., L, /_~.O,~/Ft,, F. .L, Sec. ,, T____, R Welds ., Other , M 20 AAC 25.170: LOCATION CLEAN-UP PITS: Filled In~, Liners Removed or Buried SURFACE OF PAD AND/OR 'LOCATION: Rough , Smooth ~ , Contoured__, Fiat Other , Debris RemOved , Compacted__, CLEAN UP OF PAD AND/OR LOCATION: Clean , Pipe Scrap Paper , Other SURROUNDING AREA:. , Iron Scrap Wooded , Brush , Tundra Sand __, Other , , CONDITION SURROUNDING AREA: Clean , Trash from Site Other , Wood ~ , Mud , Cement , Grass , ·Dirt , Gravel , , Trees and/or Brush from Clearing Site. ACCESS ROAD :- Dirt ,'Gravel , Ice , Other CONDITION ACCESS ROAD AND SURROUNDING: Clean__, Rough__., Smooth__, Trash frbm Operations , Trees and/or Brush from Clearing Road , Spoil from-Clearing Road' , Other RECOMHEND APPROVAL OF ABANDONMENT.' Yes . ', "No .z.--" .... Final. InspeCtion ~JO · . . .. .. _ , , 05/26/81' ' M' d ' ~ - -- Bill Sheffield, Governor ALASKA OIL AND CAS CONSERVATION-COMMISSION ~ 3OOl PORCUPII'4E DRIVE /, . ./~. !i /, , :,..., ~,~ DATE: February 26, i98.6 . / TO: R.H. Reiley~ District Drilling Engineer SOHIO ALASKA PETROLEUM COMPMIY .. P. O. Box 6612 Anchorag.e~ Alaska 99502-6612 RE: We 11 Sohio Sag Delta No. 11 LOC. Sec. 27-T11N-R16E UPM Permit No. 84-182 We wish to bring to your attention that the Commission has not yet received 6he following required items on the subject well which our records indicated was completed .. April 8: 1985: BR%EF '0~ "DESCRi~:P~i'i:ONS ~ Core Co~e #1:9201-9262 Core #2:9262-9272 Core #3:9272-9282 Core #4:9282-9342 Core #5:9342-9352 Core #6:9352-9412 Core #7:9412-9472 #2:9472-9532 Core #9:9730-9789 Core #10:9789-9817 Core #11:9817-9876 Core #12:10,056-10-094 Core #13:10,094-10-119 Article 536(b) of Title 20,. Chapter 25, Alaska Administrative Code, stipulates that this material shall be filed within 30 days after completion of a drilled-well. Please submit the above missing material. ~__~~ ~~,e r E~~~_,~ C. V. Chatterffon/ Chairman lc..C. 024 SOHIO ALASKA PETROLEUM COMPANY 900 EAST BENSON BOULEVARD ANCHORAGE, ALASKA TELEPHONE (907) 561-5111 P.O. BOX 6612 ANCHORAGE, ALASKA 99502-0612 Date: Trans #: 2-18-86 /o/ TO: State of Alaska Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 REFERENCE: Magnetic Tapes and Logs The following material is being submitted herewith. Please acknowledge receipt by signing a copy of this letter and returning it to this office: Open Hole Logs ~'~'t%~ ~-~ ~ L ~3 9~ye/ ~ 3- ! / ~Sag Delta #11 unshifted March 4, 1985 Run # 1, 2, 4, 5 86.5-10431.5 ~Sag Delta #11 shifted March 4, 1985 Run # 1, 2, 4, 5 86.5-10431.5 Lisburne L5-24 June 9, 1985 Run # 1, 2, 3, 6 110.0-12194.0 TVD Logs 1 each Blueline and Sepia .... 2" LSS Received Date KL:slt:2/18/86 0693R F}VED Alaska 0]~ & Gas Cons. Commission MEMORANDUM TO: THRU: Stat r of Alaska ~ASF~I OIL ~J~D GAS CONSERVATION COI~ISSION C. V~ ~ '~.a~te~zton Chai~~'~-k'~'/ /? ~" Lonnie C. Smith ~ Commissioner FROM: Bobby D. Foster~ ~: SUBJECT: Petroleum Inspector DATE: FILE NO: September 17, 1985 D.BDF.87 TELEPHONE NO: Location Clearance Sohio - P.B.U. Sag Delta ¢~il Petnnit No. 84-182 Lisburne Oil Pool __Friday, Au ustg~_~~,:: :~-1985'. ~ . Dick Maskell and I visited this location and as the attache~ pictures show, the pad is smooth and the reserve pit has been backfilled. The flare pit embankment has not been removed. There are a fe~-z boards and a few pieces of trash on and around the pad area that needs to be removed. I recommend to the Commission that this location not be accepted until the flare pit embankment is removed and the trash and boards are removed. Attachment 02-001AfRev. 10/79) S'£ATE ,.:t' ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION SURFACE ABANDONMENT REPORT 20 AAC 25, ARTICLE 2 FILE INFORMATION: · ' ~._ Operator ~ j'~PW~--~ Date Down~ole P & A Address ~.. ~,~O~ ~- ~ [Z ~ ~~~~_ ~ Surface Location of ~ell ' ~"" Permit No. f!7 'Ft L, Ft. F S [TN O M. 20 AAC 2~.120: WELL ABANDONMENT MARKER: AP1 No. 50-/p2~ unit Lease Name Well No. ./.t? ' Field & Pool Dia. Steel Post (4"Min.) . ~ Length (10' Min.) Height Above Final Grade' Level (4' Min.i · ~ ~' Top of Marker Pipe Closed with: Cement Plug Screw Cap Set: On Well Head , On Cutoff Casing ~--'~.~ In Concrete Plug Distance Below Final Grade Level $/ ° Ft. in. Side Outlets: All Valves and Nipples Removed ~_~ All Openings Cl.osed ~ , With Blinds , With Cement INFORMATION BEADWELDED DIRECT~LY TO MARKER POST: (List ~ere Different from File Information) Operator Well Number .~/g Ft. F L, ]~.C~Ft., F Unit or Lea'se Name , Surface Location of Well: L, Sec ~., T __, R__ ,. Welds Other 4/~/~ , M 20 AAC 25.170: LOCATION CLEAN-UP PITS: Filled In~, Liners Removed or Buried SURFACE OF PAD AND/OR LOCATION: Rough , Smooth ~,/ , Contoured , Flat Other , Debris Removed , Compacted , CLEAN UP OF PAD AND/OR LOCATION: Clean , Pipe Scrap Paper , Other , Iron Scrap SURROUNDING AREA' Wooded , Brush , Tundra Sand. , Other ..... /~//~ / CONDITION SURROUNDING AREA: Clean Other , Wood ~ , Mud , Cement , , Grass ,-Dirt , Gravel , Trash from Site__, Trees and/or Brush from Clearing Site ACCESS ROAD: Dirt ,'Gravel _ ,. Ice , Other CONDITION ACCESS ROAD AND SURROUNDING: Clean__, Rough , Smooth , Trash from Operations , Trees and/or Brush from Clearing Road __, Spoil from Clearing Road Other REC0bffIEND APPROVAL OF ABANDONMENT: Yes No z..~ Final Inspection INSPECTED BY . ! DATE - /~ 05/26/81 - ;ELTE 5 2 ~_t3 SOHIO ALASKA PETROLEUM COMPANY 311 1 "C" STREET ANCHORAGE, ALASKA TELEPHONE (907) 265-0000 MAIL: POUCH 6-612 ANCHORAGE, ALASKA 99502 TO: Mike Minder State of Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Date: __ ~.1~/~ REFERENCE: The following material is being submitted herewith. Please acknowledge receipt by signing a copy of this letter and returning it to this office:-- Core Summary Sag Delta 911 Core Chips (Conventional Core) Sag Delta ~11 (3 containers) Core Plug Ends/Core Chips L5-24 (1 large box) Dry Cuttings L-25 Dry Cuttings Sag Delta ~11 (4 containers) RECEIVED DATE 19 Technical Documentation Records Management Mylar 1FBL&IFS 1FBL 1FBL 1FBL SOHIO ALASKA PETROLEUM COI91PANY TO: ARCHIVES State of Alaska Mike Martin Lisburne Group. working file 3111 "C"SIREET ANCHORAGE, ALASKA TELEPHONE(907) 265-O000 MAIL:POUCH 6-612 ANCHORAGE, ALASKA 99502 Date: T#: 08/06/85 76360 Page 1 of 2!! REFERENCE: Sag Delta #11 Open & Cased H~S The following material is being submitted herewith~_~ acknowledge receipt by signing a copy of this letter and returning it to this office:-- DIL/SFL 01/11/85 & #1 103-2673 Sch 5" & 2" 01/23/85 & #2 2684-9170 02/'15/85 & #4 9165-9993 03/04/85 #5 9998-10396 DIL-Micro/SFL 02/16/85 #4 9165-9986 Sch 5" & 2" 03/05/85 #5 9998-10386 BHCS 01/11/85 #1 103-2640 Sch 5" & 2" 01/23/85 #2 2684-9136 02/15/85 #4 9165-9960 03/04/85 #5 9998-10360 LSS/GR Delta 02/15/85 #4 9165-9986 Sch 5" & 2" 03/04/85 #5 9998-10358 LSS/GR Wave. 02/15/85 #4 9165-9986 Sch 5" LSS-Wave.&DT 03/04/85 #5 9998-10399 Sch 10" FDC/CNL-Poro 02/i5/85 #4 9165-10000 Sch 5" & 2" " 03/04/85 #5 9998-10399 Sch FDC-Raw 02/15/85 #4 9165-10000 Sch 5" & 2" 03/04/85 #5 9998-10399 EPL 03/04/85 #5 9998-10382 Sch 5" & 2" Nat'l GR 02/15/85 #4 9165-9944 Sch 5" & 2" 03/04/85 #5 9998-10367 MPL 02/16/85 #4 9200-10000 Sch 5" 03/04/85 #5 9998-10401 MPL 02/16/85 #4 9200-10000 Sch 2" 03/04/85 #5 9998-10401 CPL-Cyberlook 02/15/85 #4 9165-9950 Sch 5" 03/05/85 #5 9998-10360 RECEIVED DATE SOHIO ALASKA PETROLEUM COMPANY 3111 "C'° STREET ANCHORAGE, ALASKA TELEPHONE (907) 265-0000 MAIL: POUCH 6-612 ANCHORAGE, ALASKA 99502 TO: Date: T#: 08/06/85 76360 Page 2 of 2!! REFERENCE: Sag Delta #11 Open & Cased Hole F~PK~S The fo~owimg rnateria~ is bei.§ submitted herewith./P~lea'se ackmow~ed~e receipt by si~.i.~ a copy of this ~etter amd retumi.~ it to this office:-- SHDT-Dual Dip/GR 02/16/85 #4 9165-10000 Sch 5" 03/05/85 #5 9998-10398 Fracture ID 02/17/85 #4 9165-9986 Sch 5" 03/05/85 #5 9998-10398 Temperature 02/15/85 #4 9165-10000 Sch 5" 03/05/85 #5 9998-10398 03/04/85 #5 9998-10399 CBL/VDL 03/05/85 #1 8600-10000 Sch 5" RECEIVED DATE SOHIO ALASKA PETROLEUM COMPANY 3111 "C" STREET ANCHORAGE, ALASKA TELEPHONE (907) 265-0000 MAIL: POUCH 6-612 ANCHORAGE, ALASKA 99502 TO.' State Date: TO: o8/o~/8s 76347 REFERENCE: Sag Delta #11 ~ The following material is being submitted herewith. Please acknowledge receipt by signing a copy of this letter and returning it to this office:-- Sag Delta #11 Mudlog 104'-10400' 1/9/85 to 3/3/85 EXLOG 2" RECEIVED DATE LR2-1 Technical Documentation Records Management ALASKA OIL AND 8AS CONSERYATION.~,OMMISSION Bill Sheffield, Governor 3001 PORCUPINE DRIVE ANCHORAGE,ALASKA 995014'3102 TELEPHONE(007) 279,-1433 RE: Well ~ -- Permit No. ~ -- / ~. _ We wish to bring to your attention that the Commission has no~ yet received the following required items'on the subject well which our records indicated was completed ~-O~-'~J~~ Article 536(b) of Title 20, Chapter 25, Alaska Administrative Code, stipulates that this material shall be filed within 30 days after completion of a drilled.well. Please submit the above missing material. Chairman lc:C.024 SOHIO ALASKA PETROLEUM COMPANY 900 EAST BENSON BOULEVARD ANCHORAGE, ALASKA TELEPHONE (907) 561-5111 P.O. BQX 6612 ANCHORAGE, ALASKA 99502-0612 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. BP 41 -33-1 2-1 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 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 (lO-Il-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 -Ni akuk #4 Ni akuk #5 Mr. C.V. Chatterton July 22, !985 Page 2 Sag Delta #11 is now ready for final inSpection of the abandoned well. 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 May 8. 1985 ANCHORAGE, ALASKA TELEPHONE (907) 276-5111 MAIL: POUCH 6-612 ANCHORAGE, ALASKA 99502 Alaska Oil and Gas Conservation Commission 3001 Purcupine Drive Anchorage, Alaska 99501 Attn: Mr. C. V. Chatterton Gent lemen: Well Sag Delta #11 Enclosed, in duplicate, is Form 10-407, Well Completion Report for the above named well together with the Well History. Well Logs and Directional Survey will be mailed separately. This well has been plugged and abandoned. Very truly yours, R. H. Reiley ~ District Drilling Engineer RHR:IBG:elw 5885/0252w Enclosure cc: Well File ~17 STATE OF ALASKA ALASK.' ¢ ':,ND GAS CONSERVATION C-' -'SSION WELL COMPLETIUN OR RECOMPLETIOI ' i=.PORT AND LOG 1. Status ~ GAS [] SUSPENDED [] ABANDONED~. SERVICE [] ! 2. Name of Operator 7. Permit Number Sohio Alaska Petroleum Company 84-182 3. Address 8. APl Number P.O. Box 6-612, Anchorage, Alaska 99502-612 5o-029-21203 Classification of Service Well 4. Location of well at surface 317~ EWL, 1329~ SNL, Sec. At Top Producing Interval 317' E~CL, 1329' SNL, Sec. At Total Depth 394' E~ZL, 1346' SNL, Sec. 27, TllN, R16E, UPM 27~ TllN, R16E, UPM 27, TllN, R16E, UPM 5. Elevation in feet (indicate KB, DF, etc.) KBE = 46.65' ~SL 6. Lease Designation and Serial No. ADL 363917 9. Unit or Lease Name ADL 363917 10. Well Number Sag Delta #11 11. Field and Pool Prudhoe Bay Lisburne Pool 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 15. Water Depth, if offshore 16. No. of Completions 1/9/85 3/3/85 4/8/85 N/A feet MSL N/A 17. Total Depth (MD+TVD) 10,400'MD 10,350' 18.Plug Back Depth (MD+-FVD) TVD N/A 22. Type Electric or Other Logs Run See Attachment #1 19. Directional Survey I 20. Depth where SSSV set 21. Thickness of Permafrost YES [] NO [] [ N/A feet MD 1700 ' 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 20" 133# K-55 Surface 73 26" 200 sx Cold Set II 13 3/8" 72# L-80 Surface 2688 II 9 5/8~' 47# L-80 Surface 9182 8668 7fl 4 1/2" 29# 12.75# L-80 L-80/DS: 9893 9998 10400 24. Perforations open to Production (MD+TVD of Top and Bottom and interval, size and number) 27. Date First Production Date of Test Hours Tested 11 3958 cu.ft. Cold Set 1250 cu.ft. Class G ~ Ge1+575 cu.ft C] 623 cu.ft. Class G 9 86 cu.ft. Class G 5/8" Csg. Cut@50 25. TUBING RECORD SIZE 4~" 12.75# L-80 DEPTH SET (MD) 9.20' PACKER SET (MD) 9120' FB-1 packer 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) I AMOUNT& KIND OF MATERIAL USED I 5/8" x 13 3/8" annulus 282 cu.ft. Cold Set I follow( Arctic Pack 9886' 9740' 'G' 'G'+13 cu.ft PRODUCTION TEST ~bOve. (Cont. on ~ MethodofOperation(Flowing, gaslift, etc.) pag See attached Sag Delta #11 DST results 40 cu. ft. Class 32 cu. ft. Class PRODUCTION FOR TEST PERIOD I~ OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO Flow Tubing Casing Pressure CALCULATED.I~ 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 of oil, gas or water. Submit core chips. assG BGL d 'ay :e) Form 10-407 Rev. 7-1-80 CONTINUED ON REVERSE SIDE Submit in duplicate 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. 31. LIST OF ATTACHMENTS 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed Title Drilling Engineer Date I O ' % Y INSTRUCTIONS General' This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells' Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5' Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage 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. Item 28' If no cores taken, indicate "none". Form 10-407 January 1985 WELL HISTORY Drilled 26" conductor hole to 73'. Set cellar and 20" conductor. Cemented conductor with 200 sx Cold Set II. Installed and function tested diverter system. Spudded well at 1800 Hours, 1/9/85. Drilled 17 1/2" surface hole to 2690'. Ran open hole logs. Ran 66 jts. 13 3/8" 72# L-80 Buttress casing to 2688'. Cemented casing through DP with 3880 cu. ft. Cold Set Iii Performed 80 sx Cold Set II top job. Nippled up and tested BOPE, okay (witnessed by B. Foster, AOGCC). Tested casing to 3000 psi, okayl Drilled out float equipment and shoe. Drilled to 2715'; performed leak-off test to 0.614 psi/ft, gradient. Drilled 12 1/4" hole to 9190'. Ran open hole logs. Ran 237 jts. 9 5/8" 47# L-80 Buttress casing to 9182'. Cemented with lead slurry of 1250 cu. ft. Class 'G' with Gel and tail slurry of 575 cu. ft. Class 'G' neat. Tested casing to 3000 psi, okay. Installed and tested packoff to 5000 psi~ Tested BOPE. Injected conventional mud into 9 5/8" x 13 3/8" annulus. RIH and tagged cement at 9047'. Tested casing to 3000 psi. Downsqueezed the 9 5/8" x 13 3/8" annulus with 282 cu. ft. Cold Set I cement followed by Arctic Pack. Cleaned out cement, float equipment and shoe. Drilled to 9198'; performed leak-off test to 0.7 psi/ft gradient. Cut conventional core #1 from 9201' - 9262'. Cut pressure cores ~2 & 3 from 9262' - 9272', and 9272' to 9282' respectively. Cut conventional core #4 from 9282' to 9342', pressure core #5 from 9342' to 9352'. February 1985 RIH with test string to 9342'. Displaced string to N2, set packer. Adjusted N2 pressure. Opened slip joint safety valve for 5 minute flow. Shut-in for 1 hour. Flowed well for 4-1/2 hours. Shut-in for PBUi Reversed out contents of test string. Unseated packer. Pulled test tools. Tested BOPE. Cut cores from 9352' to 9412', 9412' to 9472' and 9472' to 9532'. Drilled 8-1/2" hole to 9730'. Cut cores from ~730' to 9789', 9789' to 9817', 9817' to 9876'. Ran open hole logl Tested BOPE. RIH and positioned DST tools. Set packer. Opened tool for 5 minute flow' Shut-in for 1 hour. Opened tool for 4 hours. Shut-in for 6 hour PBU. Released packer. Reversed out contents of test string. Drilled 8-1/2" hole to 10,010'. Ran open hole logs. Ran 33 jts. 7" liner to 9998'. Cemented liner with 623 cu. ft. Class 'G' cement with additives. Cleaned out cement to top liner at 8668'. Tested liner lap to 3000 psig. Cleaned out cement. Tested liner to 3000 psig. Drilled out shoe and 6 ft. new hole; performed leak-off test to 0.6 psi/ft, gradient. Drilled 6" hole to 10,056'. Cut cores from 10,056' to 10,094', and 10,094' to 10,119'. RIH with test tools. Set packer. Pumped 40 bbls. 9.6 ppg brine and injected 15 bbls to formation. Pumped 40 Dbls 9.6 ppg brine, 1000 gal NARC-200 and 1000 gal acid. Displaced with diesel. Injected 20 bbls brine and NARC and acid and 10 bbls diesel into formation. Shut-in well. Flowed well. Shut-in for PBU. Unseated packer. Reversed out contents of test string. Pulled test tools. Tested BOPE. Drilled 6" role to 10~220'. March 1985 Drilled 6" hole to 10,400'. Ran open hole logs. Ran VSP and gyro· Ran 13 jtsl 4 1/2" 12.75% L-80 DSS liner with shoe at 10,400' hanger at 9,893'. Cemented liner with 75 sx Class 'G' cement. Tested casing to 3000 psi. Drilled out landing collar, plugs and cement to 10,310'. Displaced well to 9.6 ppg NaC1. Ran CBL/GR and temperature logs~ Ran %4 DST tools; set packer at 9858'· Tested BOPE to 5000 psi. ~ested packer and DST string to 3000 psi. Perforated from 10,042' to 10,052, 10,014' to 10,110' and 10,252'to 10,262'. Flowed well. .Reversed produced fluids out of DP. POH. Ran and set 7" retainer at 9886'· Tested retainer to 3000 psi. String into retainer and established injection rate· Squeezed 40 cu. ft. Class 'G' cement under retainer· Cleaned out inside liner. Ran GR/CCL. Tested BOPE. Ran~ _%5 DST tools, set packer at 9577'. Perforated from 9870' to 9760'. Performed stimulation with HCL and diverter. Displaced with nitrogen. Flowed well. Shut well in. Lifted well with N2. Shut in well for PBU. Reversed out fluids and filled well with 9.6 ppg brine· POH with DST tools· Ran and set El-Drill at 9740'. Squeezed cement to perforations and reversed out drill pipe. Tested BOPE. Ran %6 DST tools and set packer. Filled string with nitrogen· Perforated from 9472' to 9490'. Injected stimulation fluids with nitrogen· Flowed well. Shut-in well· Reversed out fluids. Ran and set cement retainer at 9460'· Tested casing to 3000 psi. Squeezed 32 cu. ft. Class 'G' cement into perforations and layed 14 cu. ft. cement on top of retainer· Cleaned out cement to 9450'· Ran %7 DST tools and set packer, at 9012'. Perforated from 9231' to 9254'. Flowed well· Injected stimulation fluids to formation. Flowed well. Reversed out fluids· POH. Perforated from 9310' to 9320'. Ran FB-1 packer and set at 9120'· Ran 4 1/2" 12.75% L-80 tubing to 9120'· Landed tubing. Tested tubing to 1000 psi. Nippled down BOPE. Installed and tested tree to 5000 psi. Tested tubing to 5000 psi and annulus to 3000 psi Pulled plug in XN nipple Preparing for acid fracturint~ April 1985 Pumped stimulation fluids· Shut in well. Flowed well. Spent acid to surface~ Flowed well· Lifted well with nitrogen from 5000' and from 8300'· Flowed well· ND tree. NU and tested BOPE. Unseat tubing. Squeezed cement to perforations· Layed cement plugs above packer and across top of 7" line, and at 2000'. Cut 9 5/8" casing at 50' BGL and removed cut-off. ND BOPE. Removed wellhead. Layed surface cement plug across 9 5/8" casing stub to surface. (Plug and abandonment was witnessed by B. Foster AOGCC.) Installed abandonment marker· Released rig at 0600 hrs., 4-8-85. IBG/elw/5/8/85/0250w Attachment Well SD #11 22 Type Electric or other Logs Run DIL/SP/BHCS/GR DIL/SP/BHCS/GR GR/LDT/CAL DIL/SP/GR/ BHCS LDT/CNL/NGT ASS/GE Prox/ML DnA/GE/ MSFL FDC/GR Dipmeter DIL/SP/BHC/GR LDT/CNL/NBT/Temp/CAL EPT/GR/CAL DIn/ASS/GE SAn/MA DLL/MSFL/GR FDC/GR SHDT CBL/VDL/GR/CCL CBL Gyro VSP Surface - 2670' 2684' - 9178' 9872' - 9164' 10,002' - 9166' n n 10,002' - 9166' 10,400' - 9998' 10,400' - 9998' 10,400' - 9998 10,400' - 9998 10,400' - 9998 10,400' - 9998 10,400' - 9998 10,400' - 9998 9,998' - 8600 10,308' - 9880 Surface - 10,400' IBG/elw/5785/0250w Continued from Well SD ~11 Item #26 9460' 9120' 8745' - 8595' 1995' - 1895' 50' BGL Surface 32 cu ft. Class 'G' + 14 cu. ft. above squeezed 60 cu. ft. into perfs, laid 24 cu. ft. on top of packer 57 cu. ft. Class 'G' 48 cu. ft. Cold Set II 56 cu. ft. Cold Set I IBC/elw/5i085/0264w DST NO. 1 (OH) 9,165'-9,352' BKB ZONES 12, 13 2 (OH) 9,730'-9,876' BKB ZONES 9A, 9B 3 (OH) 9,998'-10,119' BKB ZONES 6, 7, 8 4 10,042',10,052' BKB lO,104'-lO,110' BKB 10,252'-10,262' BKB ZONES 5, 6 SAG DELTA #11 DST RESULTS STIMULATION FLUIDS (BBLS) NONE PRODUCED FLUIDS (BBLS) 31' FLUID RISE FT - 4.3 HOURS COMMENTS NO HYDROCARBONS RECOVERED FROM REVERSE OUT. Kh - 0.51 md-ft S-0.5 NONE 63' FLUID RISE FT - 4 HOURS Qi ' 36 BPD Qf - 1.2 BPD MUD W/TRACE OIL RECOVERED FROM REVERSE OUT. Kh - 4.1 md-ft S = -1.6 40 BBLS BRINE 24 BBLS NARS-200 24 BBLS 15% HCI 1 34 BBLS DIESEL TFI -~ 222 BBLS Qi ' 480 BPI) ' 17.5 HOURS TFO- 482 BBLS FINAL WC - 100% C1- - 19,000 ppm FORMATION FLUIDS: OIL - 38 BBLS WATER - 222 BBLS Kh = 79 md-ft S : -4.7 24 BBLS NARS-200 24 BBLS 15% HiCI 60 BBLS DIESEL NITROGEN CUSHION TFI : 108 BBLS Qi = lOO BWPD Qf: 80 BWPD FT = 12 HOURS TFO = 23-6 BBLS FIN'AL WC = 99% CL- = 31,000 ppm FORI~AT. ION 'FLUIDS: OIL : TRACE W)~TER : 1 28 BBLS Kh = 140 md-ft S = -3.0 DST NO. 5 9,760'-9,870' BKB ZONES 9A,gB 6 9,472'-9,490' BKB ZONE 11B 7 9,231 '-9,254' BKB ZONE 1 3 3_' 7B 9,231 '-9,254' BKB 9.,31 0'-9,320' BKB ZONES 12, 13 SAG DELTA #11 DST RESULTS STIMULATION FLU IDS (BBLS 3 STAGES 153 BBLS 3% KC1 81 BBLS CAUSTIC ll6 BBLS 9.6 ppg BRINE 225 BBLS STIMULATION lO BBLS DIESEL TFI =, 585 BBLS PRODUCrED FLUIDS (BB'L.S) = 445 BPD (slugging) ve: 0 (w~11 dted) FT : 8'4 HOURS TFO = 636 BBLS COt.~MENTS FINAL WC : 100% C1- : 50,000 ppm FORMATION FLUIDS. OIL : 82 BBLS 6 BBLS 15% HC1 18 BBLS NARS-200 36 BBLS 28% HC1 25 BBLS DIESEL TFI : 85 BBLS Qi : 5'22 BPD Qf = 212 BPD FT = 25 HOURS TFO = 476 BBLS FINAL WC = 100% C1- : 16,000.ppm FORMATION FLUIDS: OIL : TRACE WATER : 391 BBLS 12 BBLS 15% HC1 18 BBLS NARS-200 36 BBLS 28% HCI 10 BBLS DIESEL TFI = 75 BBLS FQ~ = 90 BPD : 16 HOURS TFO : 103 BBLS NO FLUID TO SURFACE RO WC = 96% FORMATION FLUIDS: OIL - TRACE WATER = 28 BBLS 1332 BBLS ACID/WATER 145 BBLS DIESEL 145 BBLS 9.6 ppg BRINE TFI = 1622 BBLS Qava "450 BPD F?~ 84 HOURS TFO = 1557 BBLS WELL RATE SLUGGING W/N2 LIFT, WELL D'IED. FINAL WC -' 98% C1- = 35,000 ppm FORMATION FLUIDS' OIL = 63 BO SOHIO ALASKA PETROLEUM COMPANY 900 EAST BENSON BOULEVARD ANCHORAGE, ALASKA TELEPHONE (907) 561-5111 P.O. BOX 6612 ANCHORAGE, ALASKA 99502-0612 March 6, 1986 Mr. C. V. Chatterton Chairman, Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501-3192 Dear Mr. Chatterton: Attached are wellsite core descriptions for your files from Sohio well Sag Delta 11. It is hoped that the delay in receiving this information has not caused any inconveinence. Sincerely, D. W. Fisher 0il & Gas Ct)ns, Co,,,,n .... Inn bcc: K. Lauder V. L. Aldridge DWF:slt:3/6/86 0737R -! RATE OF PENETRATION (FT/HR) DEPTH q2.~2 q2o,/ q2o6 q2.o8 qLIO LITHOLOGY FRAC TURE8 ! i,RZ DESCRIPTION DI~8. ETC. iPOROGITY i I I i 5 10 1~ SHOW DESCRIPTIONS ( · I ii _ Fid RATE OF PENETRATION ' & (FTIHR) · I I I Iil . I I 1 I Ill I ! I ! 11 1 ) l,l i l i' 11I. I ' ' l I I i I 1 ) ~ I I I I i ! i } ' I! i _ i I ! il { ) I I i I il i · ] I I' ! I I! l ~ I I ! I Ii I ! I t 1 !I I I i I !1 1 ! I I Xl I · i t I I ]i l I I I l"l 1 : I I ! I 11 ! - i ! I I !1 1 i ! I ! !! 1 I l ! ! Iil , ~,1 , t [ i I I!1 '.U. il II ,,, ~* t I i ! 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CORE DEPTH F~ DESCRIPTION Oct. c~ OOLiTiC P~Ks'ro~uE ~ 7'rtno t~RGILLRCEoo~ ) D OLo~ ) CRLCITi~ ~R POROSITy H~'DR ' ~O-CARBON · : SHOW DEBAR RATE F PGH~TRATION · (FTIHR)'.?' ~ ;. ! ! ,' "CORE DEPTH .,L RATE OF PENETRATION (FT/HR) CORE DEPTH GRAPHIC I8TRUcTtmEs FRAC TURE8 IZ~o -- q2 ~,2 ~'1 [ I ,l q2 ?$72. - ,, . DESCRIPTION , NO T£: L ~'ft, do3 / SpotS)/ d~ll 4'lw)rj' ~Ve c u'T .s¥c¢o, mi n_q RAT~ OF PE~'TRATIO~ DEPTH crrHoLoaY q27¢ q28o q2~2 q2~4- q2~g FRAG TUREe DIP&. ETG. L DESCRIPTION ca. lc · (.s-I o,,,. ,,.,,ct,..> POROSFTY I ..,& ,& 8HOW DESCRIPTIONS :no c.O-t-. )Vo ~lu<)?/ no c~rt' no cot -- Cola ~t,,,--- N o C l~,o,- IA Jo RATE OF FENETRATION DEPTH q~qo qzqz qz.9¥ oma,. ETC~ ,, ,., L L DESCRIPTION ~., ;+ix e.c~ a.n,'< PO.OSr~¥ SHOW DEscRIPTIONS ~o o,4 Pq. I~. v¢{l~"-' p,.l.,, yzllo,,,, .~luor> coat. ~o Fluoc') ,~o au'c'. RATE OF PENETRATION (FT/HR) CORE DEPTH GRAPHIC LITHOLOGY ~F q3 17. STRUCTURE8 FRACTURE8 D~$, ETC. DESCRIPTION .,/ ~ pcr~+). . 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""~ ....... : ' '" .... y,- .-' ' ,~ ,. . ,- ,. . ~ -. . , ,:: ........ ... :: .._...:., ....:...::;?. . . . . _ ,.:.--. ~t.-' ~.~.,~ ~,_-' ~- , · · ~ .... ' - .. :' .-" ¥,.~,:: .... . :: .~'. :.... ' "'. ' - "'. -"- '''~ '4..; .' 'z -.~X: .... ,.:'....C..~...~.)~:;.,y;.,..:..,.: ~.:.:~;~.~.~.~.:.... . .. .v': . - J ?~ ~ .... ' .,' ' "."" ~ ~ · · ' ' , .' , . :~..'~x~.~'~. '.~ -". '~ '".': 'd ' ' ..~. .n~ ,;...~-.~ .'~..'~....,~:, ..,~..~ ~'~-'%.,2' ~;': '-. '~'~';'~"~ :- ~",'"-. · ~,--;?:-;, ~ ":~ · .~ ' }~: " '~' .... "' ~.F~~,~': ,'~:- '"~'.~'~'h .-' .. -; ~ ~ ~. .-- v . .' -c.r.:,,' ~a.:.: ~'~C~'"' "- ..... c.. : .- .... . :.; .'.r':"...:'~,--~'' '."..~5~.?rC;~:~5%}.,'~-.<::~" ';:;~:~'-Y.:.'7'~('~'?Fy[-~.-~,5;'.'/'/: '- ..... ' ' ~" ' " ..* ~ ~, ~_ ~ _?- _ ~-_,___~ ~ ~ ~ .... -; ..... ~ I .... SOHIO ALASKA PETROLEUM COMPANY 900 EAST BENSON BOULEVARD ANCHORAGE, ALASKA TELEPHONE (907) 561-5111 P.O. BOX 6612 ANCHORAGE, ALASKA 99502-0612 Date: February 20, 1986 Trans #: 103 TO: State of Alaska AOGCC 3001 Porcupine Drive Anchorage, Alaska 99501 REFERENCE: Sag Delta 11 Routine Core Analysis The following material is being submitted herewith. Please acknowledge receipt by signing a copy of this letter and returning it to this office: Received Date Return Receipt: Sohio Alaska Petroleum Co. Karen Lauder MB 7-3 P. O. Box 6612 Anchorage, AK 99502-0612 KL:slt:2/18/86 0691R NO. 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20 COMPANY : WELL NAME : FILE NAME : SAMPLE I.D. - 5 6 7 8 9' 10 11 12 13 14 15 16 17 18 19 2O 21 22 23 24 CONVENTIONAL CORE ANALYSIS REPORT SOHIO ALASKA PETROLEUM CO. SAG DELTA $11 (CORE #1) RMD 900 DR DEPTH PERMEABILITY POROSITY - (md) (%) 9228.95 .01 3.70 9229.95 .01 2,00 9231.4 .01 1.50 9231.9 .02 3.10 9232.95 .12 8.00 9233.9 .03 7.50 9234.7 .61 14.70 9235~95 .07 15.40 9236.95 .13 10.20 9237.9 .09 10.20 9238.95 .05 8.20 SATURATION GRAIN DENSITY WATER OIL (g/cc) (%) (%) 2.82 46,80 41.60 2.71 20,40 79.20 2.70 5.10 94.10 2.69 3.40 84.00 2.73 30,70 46.60 2.70 20.70 59.10 2.70 27.40 42.70 2.70 16,00 45,80 2.69 22.90 54.90 2.74 39.80 36.30 2.77 50.40 25.50 9239.95 .02 6,60 2.72 40,80 52.50 9240.9 .02 5.10 2.87 71,50 10,60 9241,9 .09 7.10 2.73 26.20 36.70 9242,9 .12 9.00 9243.9 .11 6.10 9244.95 .02 5.90 9245,9 .04 7.80 9246.9 .07 7.20 9247.9 .25 13.60 2.72 38.90 41.80 2.70 31.30 34,80 2.68 18.10 60.20 2.70 24,80 74.90 2.73 33,20 43.10 2.73 50,70 35,40 LITHOLOGY/COMMENTS Ls- med gry; crpxln; dns; slty; pyr; crinal; sec Calc in Frac Ls- tn-gry; crpxln; dns; crinal; tr foss; styl; spt; frac LS- tn-gry; crpxln; dns; crinal; tr foss; styl; spt; frac Ls- tn-gry; crpxln; dns; crinal; pel; spt Ls- tn-bu: crpxln; slily'ea; crinal; foss; styl; slily spr; Sh strgrs; bur Ls- tn-bu; crpxln; slily ea; crinal; foss; pel; pcb spr; sli Hydc odor Ls- tn-bu; crpxln; ea; crinal; foss; pel; pch spt; sl Hydc od; sli mol pot Ls- tn-bu; crpxln; ea; crinal; foss; Hydc stn& odor; sli mol por Ls- it tn; microxln; foss; slily suc; spt; Sh strgrs; sec Calc in vert Frac Ls- It tn; microxln; foss; slily suc; spr; Sh strgrs; sec Calc in vert Frac Ls- it tn; microxln; foss; slily suc; spt; Sh strgrs; sec Calc in vert Frac Ls- It tn; microxln; ea; foss crinal; sec Cal in vert Frac Dol- It gry; crpxln; dns; slily rug w/ Cal in rugs; pyr; styl; foss; crinal Ls- It tn; microxln; sli vert Frac Ls- tn-bu; microxln Ls- tn-bu; microxln; slily styl; Ls- tn-bu; microxln; styl Ls- tn-bu; mtcroxln; Sh len; sli Frac Ls- tn-bu; microxln; styl; Sh len; Cbt Nod; slily suc Ls- tn-bu; microxln; styl; Sh len; Cht Nod w/ pvr: s]~1- .... NO. 21 22 23 24 25 26 27 28 29 30 31 32 COMPANY : WELL NAME : FILE NAME : SAMPLE I.D. - 25 26 27 28 29 3O 31 32 33 34 35 36 CONVENTIONAL CORE ANALYSIS REPORT SOHIO ALASKA PETROLEUM CO. SAG DELTA ~11 (CORE #1) RMD 900 DR DEPTH PERMEABILITY POROSITY - (md) (%) 9248.9 .51 14.80 9249.9 .77 16.40 9250.95 .54 15.20 9251.8 .16 11.20 9252.95 .02 10.20 9253.9 .06 6.50 9254.9 .07 7.70 9255.05 .33 9.00 9256.6 .00 7.70 9258.95 .07 6.50 9259.95 .~02 2.20 9260.8 .51 7.50 SATURATION GRAIN DENSITY WATER OIL (g/cc) (%) (%) 2.74 57.80 24.80 2.72 56.10 26.20 2.71 53.40 32.50 2.71 26.00 67.40 2.74 45.30 38.60 2.74 35.70 52.60 2.76 52.40 26.80 2.74 68.30 28.70 2.71 57.70 28.10 2.73 72.70 18.20 2.'69 78.60 19.40 2.71 81.20 5.20 LITHOLOGY/COMMENTS Ls- tn-bu; microxln; sec Calc in vert Frac Ls- tn-bu; microxln; vert Frac; tr foss; gd mol pot Ls- tn-bu; microxln; vert Frac; tr foss; gd mol pot Ls- tn-bu; microxln; vert Frac; tr foss; gd mol pot Ls- tn-bu; microxln; foss; crin; Cbt Nod Ls- tn-gry; microxln; foss; cri- nal; vert Frac Dol- gry. gn; crpxln; foss; crin; vert Frae; tr Pyr; Sh strgrs Dol-gry-gn; crpxln; dns; hvly Frac; pyr Dol-gry-gn; crpxln; dns; hvly Frac; pyr [ NO PERM (frac plug ) ] Ls-gry-gn; crpxln; dns; hvly Frac; arg; pyr Ls- gry-gn; crpxln; dns; arg; foss; crinal; hvly Frac Ls-gn-lt gry; crpxln; dns; arg I.P.; spr I.P. No. 1 2 3 5 6 7 8 9 10 11 12 13 15 16 17 18 19 2O COMPANY : WELL NAME : FILE NAME : SAMPLE I.D, _ C2 1 C2 2 C2 3 C2 4 C2 5 C2 6 C2 7 C2 8 C2 9 C2 10 C2 11 C2 12 C2 13 C2 14 C2 15 C2 16 C2 17 C2 18 C2 19 C2 20 CONVENTIONAL CORE ANALYSIS REPORT SOHIO ALASKA PETROLEUM CO, SAG DELTA !11 (CORE #2) RMD 900A DEPTH PERMEABILITY POROSITY GRAIN DENSITY - (md) (%) (g/cc) 9282.8 .02 1.30 2,71 9284.9 .02 2.70 2.70 9285.9 .01 1.50 2,70 9286.9 .02 2.30 2.70 9287,9 ,02 4.60 2,70 9288,9 ,02 4,00 2,70 9289.9 ,02 2.90 2,70 9290.8 ,03 2.50 2,71 9291.9 ,06 3,50 2,67 9292.9 ,60 4,20 2,68 9293.85 .08 2.50 2,68 9294,95 ,02 2,30 2,67 9295,9 .01 3,20 2,70 9296.85 .01 2,80 2,70 9297.95 ,01 2,40 2,67 9298.85 ,01 3,30 2,70 9299.5 .01 3.70 2,70 9300.95 ,01 2,20 2,69 9301,95 .02 4,60 2,70 9302.9 .01 1.60 2.70 SATURATION WATER OIL (%) (%) 59,50 23.10 48,10 47,00 46.50 45,90 8,50 86,50 17,00 67,90 29,00 59,00 36,00 59,.20 46,00 42.60 55,60 34.00 21,30 42,60 4,80 76,00 55,30 44,70 24,40 60,90 40,50 56,70 33,70 64,20 26.90 56,00 19,90 61,40 67,60 22,50 53.70 28,40 2,40 93.70 LITHOLOGY/COMMENTS Ls- gry-tn; crpxln; sl dol; tr pyr Ls- pred tn w/gry; crpxln; ea; glauc; sl dol; foss; crinal Ls- tn-bu; crpxln; ea; glauc; tr pyr; anhy Ls- pred tn-bu; crpxln; peld; ea; glauc; blot; fosS; crinal Ls- tn-bu; crpxln; peld; ea; glauc; foss Ls- tn-bu;crpxln;peld;ea;glauc foss Ls- tn-bu; crpxln; peld; ea; glauc; foss; tr pyr Ls- tn-gry; crpxln; sl peld; ea; glauc; foss Ls- pred bu-crm; crpxln; occ pel; ea; tr glauc Ls- tn; crpxln; occ pel; ea; tr glauc; styl Ls- bu-tn; crpxln; o¢c pel; ea; carb Ls- tn-bu; crpxln; ea; tr glauc; styl Ls- bu-¢rm; crpxln; tr glauc Ls- bu; crpxln; occ pel; tr glauc & pyr Ls- bu; crpxln; oct pel; tr glauc & pyr Ls- pred crm w/bu; crpxln; tr glauc Ls- crm-bu; crpxln; occ pel;tr glauc & pyr; styl Ls- crm-bu; crpxln; occ pel;tr glauc & pyr Ls- bu; crpxln; peld; tr glauc Ls- bu w/gry; crpxln; peld; tr glauc & pyr CONVENTIONAL CORE ANALYSIS REPORT COMPANY : WELL NAME : FILE NAME : SOHIO ALASKA PETROLEUM CO. SAG DELTA ~11 (CORE #2) RMD 900A SATURATION No. SAMPLE I.D. DEPTH PERMEABILITY POROSITY GRAIN DENSITY WATER OIL - - - (md) (%) (g/cc) (%) (%) 21 C2 20 9303.95 .01 .60 2.69 46.60 51.80 22 C2 22 9304.9 .08 1.50 2.70 69.30 19.20 23 24 25 26 27 28 29 30 31 32 C2 23 C2 24 C2 25 C2 26 C2 27 C2 28 C2 29 02 3,- .. C2 31 C2 32 C2 33 c2 34 C2 35' 33 34 35 9308.7 .01 .50 2.71 9309.2 .01 1.10 2.69 9310.1 .02 2.50 2.69 9311.15 .02 4.90 2.71 9311.95 .03 7.70 2.70 66.70 10.60 41.80 9.30 24.90 59.10 27.00 57.00 25.00 51.80 9312.95 .03 6.90 2.71 25.60 58.20 9313.95 .05 8.60 2.71 25.80 51.00 9314.85 .16 11.40 2.72 25.50 64.90 9315.9 .09 9.80 2.72 9316.9 .63 7.80 2.71 9317.9 .36 9.20 2.70 9318.95 .05 7.50 2.71 9319.95 .02 5.00 2.71 26.40 51.30 21.20 57.00 16.10 56.20 33.20 49.30 34.70 36.80 LITHOLOGY/COMMENTS Ls- bu-gry; crpxln; peld; tr glauc; foss frag Ls- pred gry w/bu; crpxln mtrx; pelds & foss frags; pyr; tr glauc; carb; crinal Ls- bu; crpxln; occ pel; foss frags; pyr; tr glauc; carb; crinal Ls- bu; crpxln; occ pel; foss frags; pyr; tr glauc; carb; crinal; w/occ Calc xls Ls- bu; crpxln; occ peld; foss frag; pyr; glauc Ls- tn; arp-microxln; oco peld; pyr; glauc Ls- tn; crp-microxln; peld; tr Pyr & Glauc; carb; crinal; occ Calc xls Ls- tn; crp-microxln; peld; tr Pyr & Glauc; carb; crinal; occ Calc Ls- tn; crp-microxln; peld; pyr & glauc; tr carb; occ Calc xls Ls- tn; crpxln mtrx; occ sm peld; tr pyr & glauc; occ sml Calc xls Ls- tn; crpxln mtrx; sm peld; tr Pyr & Glauc; foss frags & sm Calc xls Ls- tn; crpxln mtrx; sm peld; tr Pyr & Glauc; foss frags & sm Calc xls Ls- tn; crpxln mtrx; sm peld;tr Pyr & GlauC; occ Calc xls & foss frags; crinal; carb Ls- tn-g'ry;crpxln;sm pelds; pyr&glauc;tr carb;crinal Ls~ tn-gry;¢rpxln;occ peld;sl pyr glauc;tr carb;foss frags;¢rinal COMPANY WELL NAME FILE NAME CONVENTIONAL CORE ANALYSIS REPORT SOHIO ALASKA PETROLEUM CO. SAG DELTA ~11 (CORE ~2) RMD 900A SATURATION No. SAMPLE I.D. DEPTH PERMEABILITY POROSITY GRAIN DENSITY WATER OIL - - (md) (%) (g/cc) (%) (%) 36 C2 36 9320.95 .07 7.60 2.73 27.10 54.80 37 C2 37 9321.9 .05 7.60 2.78 71.34 13.60 38 C2 38 9322.95 .06 8.00 2.70 31.40 51.60 39 C2 39 9323.95 .11 9.30 2.71 33.50 43.70 40 C2 40 9324.75 .05 7.40 2.71 36.60 44.70 41 C2 41 9325.85 .02 4.10 2.74 44.40 24.00 42 C2 42 9326.85 .09 3.30 2.70 34.70 5.10 43 C2 43 9327.9 .01 2.70 2.69 32.90 18.30 44 C2 44 9329.1 .04 1.70 2.69 56.50 30.10 45 C2 45 9329.95 .06 2.60 2.68 37.00 26.30 46 C2 46 9330.95 .04 7.40 2.71 32.40 58.60 47 C2 47 9331.85 .09 10.10 2.70 29.80 49.30 48 C2 48 9332.95 .16 11.80 2.70 42.10 37.20 49 C2 49 9333.95 .34 11.30 2.72 37.60 38.80 50 ~C2.50 9334.9 .36 ' 11.80 2.71 45.30 26.40 51 C2 51 9335.95 .21 10.80 2.71 31.70 40.40 52 C2 52 9336.9 .12 10.50 2.73 57.00 20.80 53 C2 53 9337.6 .04 6.30 2.71 27.60 50.40 54 C2 54 9338.6 .05 8.50 2.77 59.30 14.20 55 C2 55 9340.1 .12 6.70 2.72 61.90 28.80 56 C2 56 9341.1 .04 3.30 2,71 70.10 11.70 LITHOLOGY/COMMENTS Ls- tn;crpxln;occ peld;glauc;foss frags Ls- gry;crpxln;pyr;glauc Ls- tn-bu;crpxln mtrx;sm pelds;sl pyr&glauc Ls- tn;crpxln mtrx;sm pelds;glauc tr pyr;tr carb;crinal Ls- tn;crpxln;occ pelds;glauc crlnal Ls- tn;crpxln;occ pelds;glauc;tr pyr;crinal Ls- bu-crm;crpxln;tr glauc Ls- bu;crpxln;tr glauc&pyr Ls- tn-brn;crpxln;tr glauc Ls- tn;crpxln;tr glauc Ls- tn;crpxln;occ pelds;glauc crinal Ls- tn;crpxln;occ pelds;glauc; crinal Ls- tn;crpxln;occ pelds;glauc; foss frags;crinal Ls- tn;crpxln;tr glauc Ls- tn;crpxln;tr glauc Ls- tn;crpxln;tr glauc Ls- tn;crpxln;glauc;tr pyr;foss frags Ls- tn;crpxln;glauc;foss frags Ls- tn w/it gry;crpxln;glauc;foss frags Ls- tn w/lt gry;crpxln;glauc;tr pyr;foss frags Ls- pred tn w/lt gry-crm;crpxln; glauc;soln cvty w/pyr FILg ~B ~ CONVENTIONAL CORE ANALYSIS REPORT SOHIO ALASKA PB~ROLATIM CO. SAG DELTA ~1t (CORE RMD 900C No. SAMPLE I. D. -- 1 2 N/S 3 1 4 2 $ 3 7 5 $ 6 9 11 $ 12 9 13 10 14 11 15 12 16 13 17 14 18 15 19 16 20 17 DEPTH -- 9352-53 9353-54 9354.1 9355.65 9356.4 9357.2 9358.65 9359.5 9360-61 9361.85 9362.2 9362.9 9364.2 9366.9 9367.85 9369.25 9370.4 9371.35 9372.65 9373.2 SATURATION PERMEABILIT~ POROSITY GRAIN DENSITY WATEI{ OIL {g/cc; (~1 .42 .44 2.59 30.80 58.00 .03 1.90 2.70 70.70 23.70 .02 1.40 2.70 55.00 38.90 .17 1.40 2.70 36.30 62.80 .42 1.70 2.70 50.60 45.20 · 01 .8i 2.70 25.90 73.00 .05 4.80 2.70 38.20 59.50 .03 2.40 2.70 39.90 47.80 .04 4.10 2.68 16.90 59.30 .09 5.90 2.70 17.50 59.30 .06 8.40 2.71 33.90 43.40 .04 7.20 2.73 40.60 43.80 ,.12 8.50 2.73 70.60 29.40 .01 2.20 2.70 52.60 47.40 .04 8.20 2.74 80.30 11.10 .07 8.80 2.64 56.50 38.00 .04 6.50 2.69 59.60 30.20 LITHODOGY/COMMENTS Sh- gry-gn; calc Ls- It gry-gn; microxln; arE; dns; dol at base Ls- gry-gn; microxln; slily arE; dol at top; crinaI; vert frac Ls- gry-gn; microxln; stily arE; crinal; vert frac Ls-. gry-gn; microxln; slily arE; crinal; vert frac Ls- gry-gn; ~icroxln; mod dns; styl; crinaI; Foss frags Ls- gry-gn; microxln; mod dns; crinaI~ Foss frags; arq w/Sh lens' Ls- gry-gn; crpxln; dns; Cbt nd; bioturb; crinal; Foss ,frags Sh- calc Ls- gry-gn; microxln; slily arE; Foss frags; crinaI; slily glauc Ls- brn-gn; microxln; slily arE; slily slty; crinal; styl; slily glauc Ls- brn-gn; microxln; slily slty; styl Ls- brn-gn; microxln; silly slty~ styl Ls- brn-gn; microxln; slily arE; styl; Burs; glauc L$- brn-gry; microxln; mod dn$; silly arE: styl; crinal; Foss frag$; Sh lam Ls- gn-gry; crpxln; mod dns; arE; Sh lam; tr Crin Ls- gn-gry; microxln; arE; glauc; Sh lam Ls- dk gn;' crpxln; arE; Sh lam Ls- gn-brn; crpxln: arE; Sh lam Ls- gn-brn; crpxln; arg: Sh 1~ CONV~IONAL COR~ ANALYSIS REPORT SOHIO ALASKA PETROLEUM CO. SAG DELTA ~I1 (CORE )3) RMD 9O0C No. SAMPLE I.D. DEPTH -- -- -- 21 18 9374.2 22 19 9375.25 23 20 9376.2 24 21 25 22 26 23 27 24 28 25 29 26 )o N/S 31 27 32 28 33 29 34 30 SATURATION PERMEABILI~ POROSITY GRAIN DENSITY WATER OIL (md) (%) (~/c¢) (%) ;%) .10 9.80 2.$0 74.70 15.70 .02 6.40 2.75 66.20 24.10 .02 4.80 2.70 26.30 63.10 9377 .02 5.20 2.70 20.40 57.50 9377.95 .03 6.10 2.7I 27.20 49.90 9378.95 .09 6.20 2.70 19.20 48.30 9380.3 .05 6.10 2.70 14.00 65.90 9381.15 .04 5.80 2.70 18.80 68.40 9382.8 .04 4.60 2.71 12.50 70.70 9383.3 9384.1 .03 4.20 2.70 12.50 60.40 9384.85 .09 4.10 2.71 38.00 45.60 9385.85 .02 1.90 2.70 56.10 31.20 9387.1 LI THOLOGY/COMMENTS Ls- 9n-brn; crpxln; arg; Sh lam Ls- gry-gn; microxln; sl arg; glauc; Sh lam; Foss Frag; pyr Ls- brn-gry; microxln; Crin; foss frag; tr Glauc; sl mol Pot; sl Hydc Stn & Odor Ls- brn-gry; microxln; Crin; foss frag; tr Glauc; sl mol Por; sl Hydc Stn& Odor Ls- brn-gry; microxIn; Crin; foss frag; tr Glauc; sl mol Pot; sl Hyde Stn& Odor Ls- brn-gry; microxln; Crin; foss frag; tr Glauc; sl mol Pot; sl Eydc St~ & Odor Ls- brn-gry; microxln; Crin; foss frag; tr Glauc; sl mol ?or; sl Hydc ~tn & Odor Ls- brn-gry; microxln; Crin; foss frag; tr Glauc: sl mol Pot; si ~ydc Stn & Odor Ls- brn-gry; microxln; Crin; ~oss frag; tr Glauc; sl mol Pot: si Hyde Stn& Odor Ls- brn-gr¥; microxl~; Crin; foss frag; tr Glauc; sl mol Por~ si Hyde Stn& Odor Ls- brn-gry; micrOxl~; Crin; foss frag; tr Glauc; si mol Pot; si Hyde Stn & Odor Ls- brn-gr¥; microxl~; Crin; foss frag; tr Glauc; sl mol Pot; sl Hydc Stn& Odor Ls- med gry; crpxln; mod dns; bur; Sh lam Ls- gry-brm;microxln; s! lam; glauc; spty Pyr; vert Frac; pot {PLUG FRACTURED} COKPANY WELL NAME FILE CONVENTIONAL CORE ANALYSIS REPORT SOBIO ALASKA PE~OLEUM CO. SAG DELTA 811 (CORE 83) RMD 900C SAMPLE I.D. DEPT8 35 31 36 32 37 33 38 34 39 35 40 36 41 37 42 38 ¢3 39 44 40 45 41 46 42 47 43 9388.55 93~9.2 9389.9 9390.95 9391.9 9392.95 9393.95 9394.95 9395.95 9396.95 9397.5 939~.15 9395.9 6.30 2.70 42.60 36.70 .17 6.60 2.69 30.00 43.00 .08 5.70 2.70 33.60 38.20 .06 7.40 2.71 17.40 55.90 .14 7.90 2.70 14.00 67.50 .25 9.30 2.70 64.80 6.40 .11 8.80 2.70 21.20 50.60 .99 9.00 2.71 35.60 36.20 1.10 9.40 2.69 , 29.90 44.50 8.50 2.69 8.60 68.40 .11 8.50 2.69 32.40 38.70 .09 8.50 2.71 32.00 39.50 .05 6.90 2.69 36.00 34.40 LITHOLOGY/COMMENTS Ls- gry-brnfmicroxln; si lam; 91auc; spry Pyr; vert Frac; sl por Ls- gry-brn;microxln: sl lam; glauc; spty Pyr: vert Frac; sl por Ls- gry-brn;microxln; si lam; g[auc; spty Pyr; vert Frac; pot Ls- gry-brn;microxln; sl lam; glauc; spry Pyr: vert Frac; por Ls- gr¥-brn:microxln; sl lam; glauc; spry Pyr; vert Frac~ sl 'pot Ls- gry-brn;microxln; sl lam; glauc; spry Pyr; vert Frac; sl por Ls- gry-brn;microxln; si ]am; glauc; spty Pyr; vert Frae; st p.or Ls- gry-brn;microxln; sl lam; glauc; s~ty Pyr: uert Frac; si por Ls- gry-brn;microxln; si lam; glauc; spry Pyr; vert Prac; sl por Ls- gry-brn;micr°xln; si lam; glauc; spry Pyr; vert Frac; si pot Ls- gry-brn;microxln; sl lam; glauc; spry Pyr; vert Frac; si pot Ls- gry-brn; microxln; glauc; spry Pyr; tr Foss frags; si por Ls- gry-brn; microxln; gia~c; spry Pyr; tr Foss frags; sl pot COMPANY WELL NAME FILE NAME CONVENTIONAL CORE ANALYS I S REPORT SOHIO ALASKA PETROLB~JMCO- SAG. DELTA %11 (CORE RMD 900C No. SAMPLE I. D. -- -- 48 44 49 45 50 46 51 47 52 48 53 49 54 50 55 51 56 52 57 53 58 54 59 55 DEPTH - {md) (%) 9399.85 .01 3.30 9401.6 .06 3.20 94~2.1 .14 6.00 9402.8 9404.15 .10 4.50 9404.9 .04 5.50 9456.35 .02 3.90 9406.75 .CS 8.80 94~7.75 .05 4.10 9409.1 4.70 5.~0 9410.1 .07 4.50 94!1.15 .07 4.70 SATURATION PERMEABILITY POROSITY GRAIN DENSITY WATER OIL (g/ecl (%) (%1 P. 7o a.5o 79.60 2.72 55.10 35.60 2.74 64.60 22.80 2.70 29.90 63.40 2.69 23.30 56.60 2.73 41.10 35.10 2.70 14.10 44.30 2.77 40.60 36.40 2.70 9.30 61.50 2.70 20,30 60.60 2.71 20.60 55.90 2.71 8.10 60.1~ LITHOLOGY/COMMENTS Ls- gry; crpxln; mod dns; glauc; cryolitic~ Foss Frag Ls- gry-gn; crpxtn; dms; hvy lam; tr Pyr Ls- gry-gn; crpxln; dns; hvy lam; tr Pyr Ls- gr¥-gn; crpxlm; dns; hvy lam; tr Pyr Ls- gry-gn; crpxln; dns; hvy ]am; Cht Nod Ls- gry-gn; crpxln; dns; hvy lam: Cht Nod Ls- gry-gn; crpxln; dns; hvy lam; Cht Nod Ls- gry-gn; crpxln: dns; hvy !am; Cbt Nod La- gry-gn; crpxl~; dns; vert Frac Ls- gry-gn; crpxln; dns; sl lam; crinal; foss frag; cryotitic: Cht Nod Ls- gry-gn; crpxln; dns; sl crinal; foss frag; cryolitic; Cht Nod Ls- gry-gn; crpxln; dns; sl lam; crinal; foss frag; cryolitic; Cbt Nod COMPANY : WELL NAME : FILE NAME : COMVE[°:TIONAL CORE ANALYSZS REPORT SOHIO ALASKA PETROLEUM CO. SAG DELTA ~ !1 [CORE 4} RMD 9O0D NO. SAMPLE I.D. DEPTH 9412.3 2 2 9412.95 3 3 9413.95 4 N/S 9414-15 5 4 9415.2 6¸ 5 7 6 $ 7 9 ¸8 10 9~ 11, 12 11 13 12 SATURATION PE~tLITY POROSITY GRAIN DENSITY WATER OIL [md) (%) (g/cc) (%) (%) .02 4.00 2.70 5.40 71.98 .05 4.50 2.72 22.70 57.40 .Ol 1.00 2.70 10.60 87.40 .08 6.40 2.70 41.30 53.90 9415.95 2.50 18.80 2.78 46.6D 17.80 9416,95 1,20 16.60 2.81 49.3~ 23.70 9417.95 .72 16,80 2.83 54.70 17.10 9418.95 .56 16.40 2.77 0.00 0,00 9419.95 .19 5.30 2.69 41.80 55.40 9420.95 .06 7.80 2.68 33.50 47.50 9421.8 .00 5.80 2.71 0.00 0.00 9422.95 .02 1.40 2.71 39.90 43.00 9423-24 9424,05 .11 7,40 2,70 11.50 60.90 L I THOLOG Y/CO~'IENTS Ls- /t-med. brn; crpxln; styl; tr Sb lam; crinal; glauc; vert Frac Ls- lt-med bm; crpxln; styl; tr Sh lam; crinal; glauc$ vert Frac Ls- It gzy-lt brn; crp×ln; styl; glauc w/glauc Sh lam; crinal; foss Frag; Ls- It gry-lt bm; crpxl~; styl; glauc w/glauc Sh lam; crinal; Foss Frag; Ls- It gry-lt bm; crpxln; styl; glauc w/qlauc Sh lam; crinal; foss Frag Dol- brn-gn; vf xln; glauc; slily sndy; bur; p.p. pot; vert Frac Dol- brn-gn; vf xln; glauc; slily sndy; bur; p.p. pot; vert Frac Dol- gn; vf xln; slily sndy; arg; crinal; sl bioturbated; tr p.p. pot; vert Frac Dol- gn-gry; vf xln; arg; glauc; bur; tr Crinal; tr p.p. pot; {PLUG FRAC NO FLU/DS) Ls- gn-brn; crpxln; mod dns; sdy-slt¥; bur; Crinal; Cht ~od; sl arg Ls- m brn; crpxln; mod dns~ glauc; carb Xntclas w/ Cbt; Cbt Nod Ls- m bm; crpxln; mod dns; glauc; carb Intclas w/ Cbt; Cbt Nod;(FRAC PLOG] Ls- m brn; crpxln; mod dns; glauc; carb ]ntclas w/ Cbt; Cht Nod Ls~ gry-brn; crpxln; dns; styl; glauc w/'glauc Sh lam; Cbt Nod Ls- brn; crpxln; mod dns; glauc w/ glauc Sh lam; Cbt Nod COMPANY WELL NAME FILE NAME C0~'ENTiONAL CORE ANALYS2S REPORT SOHIO ALASKA PETROLEUM CO. SAG DELTA ~ I1 {CORE 4) RMD 900D No. SAMPLE I.D. -- -- 16 14 17 15 18 16 19 17 20 N/S 21 18 22 19 23 20 25 26 22 27 23 2[{ 24 29 DEPTH - (md) 9424.95 .08 9.65 9425.85 .07 7.50 9426.95 .~9 8.30 9427.95. .07 5.00 9428-29 SATURATION PERMEABILITY POROSITY GRAXN DENSITY WATER OIL 9429 .35 14.30 9429.95 .34 17.00 9430.95 1.45 19.60 9431.95 .12 10.80 9432-33 9433.05 .01 1.80 9433.9 .01 1.50 9434.95 .O4 4.09 9435.95 9436-37 (g/cc) (%) (%) 2.73 32.00 5~.90 2.70 3.30 76.10 2.73 45.2Q 47.90 2.69 36.7D 47.10 2.80 75.50 12.90 2.81 65.25 13.80 2.78 44.50 22.40 2.76 66.00 29.40 2.69 21.30 52.50 2.69 14.10 69.80 2.70 12.90 65.00 LITHOLOGY/COF2~IENTS Ls- bm; crpxln; mod dns; glauc w/ ~lauc ~h lam; Cht Nod Ls- brn; crpxln; mod dns; glauc w/ gI&uc Sh lam; Cbt Nod Ls- m bm; crpxln; mod dns; glauc; crin; vert Frac Ls- m bm-gm; crpxln; glauc w/ glauc Sh lam; crinal; foss Frag; styl; tr Pyr Ls- gn-bzn; crpxln; arg; sndy- silty; styl; crin; Foss Frag; tr Pyr Dol- gn-brn; vf xln; silly sndy; Foss Frag; arg; glauc; mod p.p. pot; crin Dol- gn-brn; vf xln; slil¥ sndy; Foss Frag; arg; glauc; mod pot; crin Dol- gn-hrn; vf xln; slily sndy; Foss Frag; arg; glauc; mod p.p. pot; crin DoI- gn-brn; vf xln; slily smdy; Foss Frag; arg; glauc; mod p.p. por; crin LS- ~ry-brn; crpxln; dns; styl; 'reft Frac; crin Ls- gry-brn; crpxln; dns; styl; vert Frac; crin Ls- gry-brm: crpxln; dns; styl; vert Frac; crin Ls- gry-brn; crpxln; dns; styl; vert Frac; crin Ls-~ry-brn; crpxln; dns; styl; vert Frac; crin; (FRAC PLUG NO SAMPLE) Ls- brn-gry; crpxln; dns; Cbt Nod; vert Frac COMPANY : WELL NAME : PILE NAME : ANA,._._S REPCRT CONVENTICNAL CORE - vc~ SOHIO ALASKA PETROLEUM CO. SAG DELTA $ 11 (CORE 4) R~ 900D No. SAMPLE I.D. 31 26 32 27 33 28 34 29 35 30 36 N/S 37 31 38 32 39 33 40 34 41 35 42 36 ~3 N/s DEPTH - (md} (%) 9437.05 .01 1.40 9438.1 .11 9.90 9439.1 .03 2.00 SATUP~TION PERMEABILITY POROSITY GRAIN DENSITY WATE~ OIL 9439.8 .02 1.50 9440.95 .02 1.70 9441-42 9442.3 .03 3.10 9443.15 .03 4.60 9444.1 .02 4.40 9445.0 9446.15 .38 5.~0 9446.9 .01 2.20 9447-48 9448-49 9449-50 (g/cc] (%) [%) 2.73 13.60 79.80 2.82 42.90 30.30 2.70 53.30 44.80 2.71 38.40 54.30 2.71 28.60 48.70 2.71 47.30 46.90 2.72 34.10 58.90 2.71 20.60 $5.50 2.71 29.70 61.80 2.72 34.80 53.30 L! TROLOGY/C0-~IENTS Ls- brn-gry; crpxln; dns; Cht Nod; vert Frac Ls- gry; crpxln; arg; slty; sl lam; styl; crinal Ls- gr¥; crpxln; dns; styl; crinal [grain pile); glauc; Foss Frag~ vert Frac Ls- gry; crpxln; dns; styl; crinai (grain pile); glauc; Foss Frag; vert Fzac Ls- gry; crpxln; dns; styl; crinal (grazn pile); glauc; Foss Frag; vert Frac Ls. gry; crpxln; dns; styl; crinal (grain pile}; glauu; Foss Frag; vert Frac Ls- gry; crpxln; dns; styl; crinal Igrazn pile}; tr peld; Foss Frag Ls- gry; crpxln; dns; styl; crinaI {grazn pile}; tr peld; Foss Frag Ls- gry; crpxln; dms; sty]; crinal {grain pile}; tr peld; Foss Frag Ls- gry; crpxln; dns; styl; Crin vert Frac (UNABLE TO DRILL Ls- gry; crpxln; dns; styl; crinaI (grain p±le); tr peld; Foss Prag; vert Frac Ls- gry; crpxln; dns; styl; crinal '(grain pile}; ~r peld; Foss Frag; vert Frac Ls- gry; crpxln; dns; styl; crinal (grain pile); tr peld; Foss Frag; vert Frac Ls- gry; cmpxln; dns;,styi; crinal (grai5 pile); tr peld; Foss Frag; vert Frac Ls- gry;~drpxln; dns; styl; crinak (grain pile}; tr peld; Foss Frag; vert Frac COMPANY : WELL NAME : FILE IQAME : CCNVENTIONAL CORE ANALYSIS REPORT SOHIO ALASKA PETROLEUM CO. SAG DELTA # 1t (CORE 4) RMD 9O OD No. SAMPLE I.D. 46 37 47 38 48 39 49 40 50 41 51 N/S 52 42 53 43 54 44 55 45 56 N/S 57 46 58 47 59 48 60 N/s DEPTH 9450.1 9450.9 9451.9 9452.9 9453.8 9454-55 9455.05 9455.9 9456.9 9457.9 9458-59 9459.1 9495.9 9460.9 946t-62 SATURATION PERMEABILITY POROSITY GRAIN DENSITY WAT~R 0IL .53 3.10 2.70 33.70 55.00 .15 3.80 2.70 59.40 39.10 .06 3.50 2.71 26.90 57.00 .03 2.40 2.71 28.00 68.30 .04 5.30 2.71 33.00 52.40 .46 13.50 2.73 25.70 42.80 .46 13.00 2.73 28.30 39.70 .1.8 9.30 2.73 24.80 47.70 .06 6.40 2.71 20.90 51.40 .10 5.30 2.70 38.70 50.90 .05 3.30 2.70 12.20 56.30 .02 1.70 2.70 19.40 32.50 LITHOLOGY/COM~iENTS Ls- gry; crpxln; dns; styl; cr~nal (grain pile); tr peld; Foss Frag; vert Frac Ls- gry; crpxln; dns; styl; crinal (grain pile); tr peld; Foss Frag; vert Fzac Ls- gry; crpxln; dns; styl; crinal; pyr Ls- bm; crpxln; dns; cri~al; sl x-lam Ls- bm; crpxln; dns; crinal; foss Frag; styl; tr Glauc Ls- brn; crpxln; c/inal; vert Frac; tr Pyr; sl mol pot Ls- brn; crpxl~; crina~; vert Frac; tr Pyr; s! mol por Ls- bm; crpxln; Ct±hal; vert Frac; tr Pyr: sl mol pot Ls- brn; crpxln; crinal; vert Frac; tr Pyr; sl.mol pot Ls- bm; crpxln; crinal; vert Frac; tr Pyr; sl mol por Ls- bm; crpxln; crinal; foss Frag; grain piles vert Frac Ls- bm; crpxln; crinal; foss Frag; grain, pile; vert Frac Ls- brn; crpxln; crinal; foss Fr&g; grain pile; vert Frac Ls- It gry; crpxln; dns; crinal; foss Frag; vert Frac Ls- It g.ry; crpxln; dns; crinal; foss Frag; styl; sl lam; vert Frac; tr Pyr COMPANY WELL NAME FILE NAME CONYENTIONAL CORE ANALYSIS REPORT SOHIO ALASKA PETROLEUM CO. SAG DELTA S 11 (CORE RMD 900D No. SAMPLE I.D. DEPTH 61 49 62 50 6~ 65 52 66 53' 67 ~/s 68 54' 69 N/S 70 55 9462.1 9462.85 94~3.65. 9463-64 9465.9 9466.7 9467-68 9468.6 9469-70 9470.3 SATURATION PERMF~ILITY POROSITY GRAIN DENSITY WATER OIL Ig/cc) (%) (%) .~2 3.90 2.73 54.20 38.30 · 03 3.10 2.71 60.20 29.30 .D2 1.40 2.70 36;.40 42.80 .02 4.50 2.70 40.40 34.80 .08 7.10 2.70 33.40 43.60 2.40 2.69 12,00 45.10 LIT~OLOGY/COF~ENTS L$- It gm; crpxln; dns; sl arg; gtauc Sh 1Am; styl; crinal w/ tr Pyr in Crin center 5s- it gm; crpxln; ~ns; si arg; glauc Sh lam; styl= crinal w/ tr Pyr in Crin center Ls- gry-lt gm; czpxln; styl; glauc Sh lam: uert Frac; crinal(UNABLE ~D DRILL PLUG) Ls- gry-lt gm; crpxln; dns; styL; glauc Sh lam~ hvy Frac; crinal Ls- gry; crpxln; dn$; styl; glauc Sh lam; vert Frac; crinal Ls- gr¥; crpxln; dns; styl; glauc Sb lam; uert Frac; cri~al Ls- gry; crpxln; dn$; styl; glauc $h lam; vert Frac; crinal Ls- gry; crpxln; d. ns; styl; glauc Sh lam; vert Frac~ crinal Ls- gry; crpxln; dns; styl; glauc Sh lam; vert Frac; crinal Ls- gry; crpxln; dns; styl; glauc Sh lam; vert Frac; crinal COMPANY : WELL Nk~tE : FILE NAME : No. SkMPLE I.D. 21 21 22 22 23 23 24 24 25 25 26 26 27 27 28 28 29 29 30 30 31 31 32 32 34 34 36 36 37 37 40 40 CONVENTIONAL CORE ANALYSIS REPORT DEPT~ 9495.15 9496.1 SOHIO ALASg~ PETROLEUM CO. SAG DELTA ~11 (CORE ~59 RMD 9DOE SATURATION PERMF. ABILITY POROSITY GRAIN DENSITY WATER OIL {md) (%) (g/cc] (%) (%) .07 7,90 2.71 .04 6.10 2.75 9497.05 .03 6.60 2.72 9498.2 .03 3.20 2.75 37.50 25.00 9500.25 .02 2.20 2,83 9501.15 .43 6.00 2.77 53.70 45.40 9507.95 <.01 .42 2.70 79.10 17.60 9509.$ .10 2.70 82.90 0.00 9510.8 <,01 1.60 2,71 34.8~ 61.90 9511.95 .15 2.60 2.70 54.20 45.10 9513.05 <.01 2.20 2.70 82.70 14.70 9514.05 <.01 .70 2.69 98.70 0.00 9515.~5 <.01 .42 2.69 99.60 9516.05 <. 01 1.60 2.71 51.20 48. 9517.05 .03 1.50 2.71. 59.90 32.00 9517 . 9 . 05 6.40 2.64 71 . $0 27.90 9518 · 6 · 36 . 70 2.71 34 . 10 60.70 9520.05 <.01 2.40 2.72 23.70 73.80 9521.1 .01 2.50 2.71 17.30 80.60 9522.05 <.01 .90 2.71 21.80 77.70 LITMOLOGY/COMMENTS Ls- tn-bu; crpxln; pyr; slily pel Ls- tn-bu;.crpxln; slily pel; tr Crin & Foss frags; sec Calc in frac Ls- tn-bu; crpxln; ea; pel; Crin; tr Glauc & Pyr Ls- tn-bu; crpxln; slily ea; pel; tr Crin Dol- med gry; crpxln; dns; tr Glauc Dol- grygrn; crpxln; dns; slily mrg; glauc;tr Pyr Ls- It gry; microxln; mod dns Ls- it gzy; microxl~; dns; tr Glauc & Pyr Ls- it gry; crpxln; dns; tr Glauc frac LS- It gry; crpxln; dns; glauc; sec Calc in frac; tr pel Ls- it gry; crpxln; dns; slily pyr & glauc; styl; sec Cate in frac Ls- lt-med gry; crpxln; dns~ glauc; pel; frac: sl dol Ls-med grygrn; crpxln; dns~ tr Glauc; sl pel Ls- it gry; crpxln; dns: slily glauc; pe! Ls- med gry; crpxln; dns; Foss fra~s; crinal; tr Glauc & Pyr Cht- off wk; crpxln; dns; frac; calc Ls- med gryl crpxln: dns; tr Glauc; frac Ls- it grygrn; crpxlm; dns; gla~c crinal; si Hydc stn in frac Ls- it gry; crp-microxln; dns; glauc; pel; tr Crin Ls- It gry; crp-microxln; dns; gl~uc; peI: tr Cri, n CON-VENTIO.~AL CORE ANALYSIS REPORT CO~tPANY : WELL NA~_E : FILZ NARE : SOHIO ~LASKA PETROLEUM CO. SAG DELTA ~11 (CORE %5] RMD 900E -- No. SAMPLE I.D. -- -- 41 41 42 42 43 43 44 44 45 45 46 46 DEPTH - (md] [%) 9523.05 .05 1.30 9524.2 <.01 .70 9525.3 <.~1 1.50 9526.05 .13 7.70 9529.15 .02 4.40 9529.85 .02 8.30 SATU RAT~ ON PE~BIL~TY POROSITY GRAIN DENSITY WATER OIL (g/cz) (%1 (%) 2.70 42.80 57.10 2.71 ~1.30 23.80 2.71 42.00 57.30 2.68 B~.80 18.30 2.74 85.40 13.20 2.69 59.00 40.60 LITBOLOGY/COMMENTS Ls- it gry; crpxln; dn$; $lily glauc; p~l; crinal; styl; tr Pyr Ls- It gry; crpxln; dns: tr Glauc & Pyr Ls- it gry; crpxtn; dns; tr Glauc & Pyr Cht- off wh-lt gry; crpxln: dns~ tr Glauc; calc Ls- It gry; crpxln; dns; tr Glauc Ls- med grygrn; microxln; mod dns tr Glauc & Pyr; sil COMPANY WF-LL NAME FILE NAME COI~;ENTICNAL CORE ANALYSIS REPORT SOHIO ALASKA PL~TROLEOM CO. SAG DELTA #11 (CORE ~65 RMD 9~0F - No. SAMPLE I.D. 1 1 2 2 3 3 4 4 5 5 6 5 7 7 8 10 10 11 11 12 12 13 13 16 14 15 1~ 16 18 18 19 19 DEPTH - [md) (%) 9730.1 .04 7.80 973].05 .05 2.70 9732.2 <.D1 4.38 9733.1' <.01 3.90 9733.95 .01 4.70 9734.95 .01 5.00 9535.95 .03. .71 9736.95 .60 1.80 9737.95 <.~1 2,10 SATURATION PERMEABILITY POROSITY GRAI~ DENSITY WATER OIL 9738.95 <.01 3.60 9739.95 <.01 2.70 9740.85 <.01 3.20 9?42.2 .01 3.20 9743.15 .03 3.90 9743.95 .01 3.60 9744.95 .06 6.10 9746.15 .06 5.70 9746.95 .05 6.90 9747.95 .08 5.00 9748.9 .27 5.50 fg/¢c) (%) (%3 2.69 50.80 38.40 2.72 87.60 4.50 2.78 92,60 2.00 2.75 85.90 15.00 2.83 58.20 34.00 2.96 62.10 32.50 2.71 23.30 25.90 2.71 51..35 45.60 2.71 87.05 4.80 2.72 71.10 28.20 2.75 36.40 65.90 2.72 52.30 41.70 2.69 43.20 49.20 2.69 42.00 37.30 2.70 39.60 41.50 2.69 29.90 49.90 2.71 25.60 57.10 2.73 24.90 43,00 2.23 33.90 49.90 2.76 33.10 30.80 LITHOLOGY/COMMENTS Ls- med gry-med brn; crpxln; s1 arg; tr Pyr & Cbt; si lam Ls- med gry-med bm; crpxln; arg; tr Glauc & Cht Ls- med gry-med brn; crpxln;arg; pyr; tr Cbt Ls- med gry-med bra; crpxln; arg; pyr; sl glauc; Ls- med gry-med bm; crpxl~; arg; pyr; s~ glauc Ls- grygrn; crpxln; arg; pyr Ls- grygrn; crpxln; arg; bom dns: lam Ls- wh-bu; crpxln; dns; s1 lam; sec Calc in frac; tr ~ydc stn Ls- wh-bu; crpxln; dns; si lam; tr Cbt; crina].: glauc; styl; sec Cale in frac Ls- grygrn; crpxl~; dns; styl; sl arg; glauc; pyr; crinal; sec Calc in frac Ls- gr¥-dk gm; crpxln; arg; lam; crinal: pyr & glauc Ls- grygr~; crpxln; arg; glauc; pyr; cri~al Ls- lt-med gry; microxln; sl arg; lam: tr Pyr; sec Calc in frae Ls- !t-med gry; microxln; $1 arg; lam; tr Pyr; sec Calc in frac Ls- lt-me~ gry; microxln; si arg; lam; %r Pyr; sec Calc in frac Ls- lt-me4 gry; microxln; sl sndy sl lam; crinal & glauc; sec Calc in frac Mdst- med bm; calc; slty; x-lam Mdst- med brn; calc; slty; x-lam Mdst- med brn; calc; slty; x-lam Mdst- med brn; calc; slty; x-lam COMPANY WELL NAME FILE NAME CONVENTIONAL CORE ANALYSIS REPORT SOHIO ALASKA PETROLEUM CO. SAG DELTA %11 (CORE #6) RMD 900F No. SAMPLE I.D. 21 21 22 22 23 23 24 24 25 25 26 26 27 27 2B 28 29 29 30 30 31 31 32 32 33 33 34 34 35 35 36 36 37 37 38 38 39 39 40 40 DEPTH - (md} (%) (g/cc) 9749.95 .03 5.50 2.75 9753.05 .11 8.00 2.69 9754.8 .01 1.90 2.71 9757.15 .15 4.50 2.69 9757.55 .27 8.90 2.65 9762.2 .02 2.B0 2.64 9763.05 .04 3.10 2.66 9764.05 .27 1.60 2.71 9766,35 .09 1.70 2.56 9767.05 .01 1.20 2.69 9768.2 .01 1.20 2.68 SATURATION PERMEABILITY POROSITY GRAIN DENSITY WATER 0IL 9769.45 .01 1.30 2.69 9774.3 .02 1.80 2.70 9777.2 1.60 21.00 2.~1 9779.05 3.15 19.00 2.81 9780.8 13.00 23.80 2.79 9781.95 2.70 20.50 2.73 9782.95 1.70 17.30 2.76 9783.95 .27 17,30 9785.20 1.80 16.40 {%) (%) 26.40 41.90 48.05 44.10 75,50 21.00 44.40 35.50 42.20 41.10 48.70 47.90 60.00 39.00 16.10 82.60 64.50 34.60 48.00 48.60 35.60 63.20 45.30 47.70 36.30 62.20 29.60 45.80 37.50 34.80 33.00 : 35.90 35.80 39.70 42.80 40.20 2.80 2.71 43.90 38.70 34.40 34.20 LITHOLOGY/COMMENTS Mdst- med brn; cal¢; slty; x-lam Ls- gr¥-brn; crpxln; dns; arg; tr Cbt; lam Ls- gry-brn; crpxln; dns; arg; tr Cbt; lam Ls- it gr¥; crpxln; dn$; $1 lam; occ Cbt nod; sec Calc in frac Ls- It gry: crpxln; dns; sl lam; abd Cht nod; sec Calc in frac Ls- it gry; crpxln; dns; sl lam; abd Cht nod; sec Calc in frac Ls- it gry; crpxln; dns; sl lam; abd Cbt nod; sec Calc in frac Ls- It gry; crpxln; d~s; si lam; occ Cbt nod; sec Calc in frac Ls- It gry; crpxln; dns; sl lam; abd Cbt nod; sec Calc in frac Ls-it gry; crpxln; dns; sl lam; sl crinal Ls- it gry; microxln; mod dns; tr Crin; sl lam; occ Cbt nod; sec Calc in frac L$- It gry; microxln; mod dns; tr Crin; sl lam; occ Cbt nod; sec Caic in frac Ls- It gry; crpxln; dns; styl; tr 91auc sh Mdst- dk bm: dol; $1ty; sl arg; x lam; Hydc stn; tr Cht; gd pot Mdst- dk bm; dol; slty; si arg; x lam; Nydc stn; occ Cbt nod; gd pot Mdst- dk brn; dol; slty; $1 arg; x lam; Hydc stn; occ Cht nod; gd Mdst- med bm; slty; arg; dol; sl rug; sl Hydc stn; occ Cbt nod; mod por Mdst- med'brn: slty; ar9; dol; si rug; sl. Hydc stn; occ Ch% nod; mod p0r Dol- g'ry-brn; crpxln; dns: arg; thn lam Ls- gry-brn; crpxla; dns; arg & COMPANY : WELL NAME : FILE NAME : No. SAMPLE I.D. DEPTH -- -- 41 41 42 42 CON~'_~lqTiONAL CORE ANALYSIS REPORT SOHIO AI~SKA PETROLEUK CO, SAG DELTA #11 (CORE RMD 9 SATURATION PERMEABILITY POROSITY GRAIN DENSITY WATER OIL (g/cc) (%1 (%) 9785.95 .04 5.30 2.74 20,50 73,30 9786.95 ,02 4,5~ 2,69 30.90 68.80 LITHOLOGY/CO~a~4E~TS Ls- gr¥-br.n; crpxln; dns; arg & dol; sl wug w/ sec Calc in vug; styl; occ Cbt nod Ls-gry-brn; crpxln; dns; sl arg; rug w/ sec Calc iN rug; occ Cht nod COMPANY ~4ELL ~ PILE ~ COS~:ENTIONAL CORE ANALYSIS REPORT SOHIO ALASKA PETROLEUM CO. SAG DELTA ~11 [CORE ~7) P. MD 900G · · No. SAMPLE I.D. DEPTH 21 2! 9810.85 22 22 9812.1 23 23 24 24 25 25 26 26 9813.05 9814.05 9815.1 9816.0 SATURATION PERMEABILITY POROSITY GRAIN DENSITY WATER OIL (md} (%) (g/cc) {%) (%) .01 .90 2.72 4.20 88.20 .06 2.00 2.69 17.40 81.00 .01 1.00 2.63 18.$0 79-50 .Ol 3.00 2.64 37.60 61.30 .01 1.90 2.71 62.50 33.10 ( .01 1.2-0 2.60 69.40 30.80 LITHOLOGY/COMMENTS Ls- med-dk gry; crpxln; dns; styl bioturb; crinal Ls- med gry-med bm; crpxln; dns; foss; crinal; bioturb; si styl; alg Deb Cbt- it gry-blugry; hd; smwt calc tr al9 Deb Cbt- At gry-blugr¥; hd; smwt calc sl dol; tr alg Deb Ls- dk gry-brn; crpxln; dns; foss crinal; styl; alg Deb Cht- med gry-blugry; hd; calc ip; tr alg Deb CONVENTIONAL CORE ANALYSIS REPORT COMPANY : WELL NAME : FILE NAME : No. SAMPLE I.D. 2 2 3 3 4 4 5 5 6 6 7 7 9 9 10 18 12 12 13 13 14 14 15 15 16 16 lY t7 18 18 19 19 20 20 SOHIO ALASKA PETROLEUM CO. SAG DELTA #11 {CORE #7) RMD 900G DEPTH - [md] (%) 9789.05 .0B 6.40 979D.6 .02 3.00 9790.95 .01 4.00 9791.1 .17 4.10 9792.7.5 .90 4.70 9794.25 .01 2.50 9794.95 .03 3.10 SATURATION PERMEABILITY POROSITY GRAIN DENSITY HATER OIL 9796.2 .02 2.20 9796.9 .04 2.10 9797.85 .O2 2.00 9798.95 .03 .60 9799.95 9801.25 .57 2.80 9803.95 .03 .80 9805.05 .06 .60 9806.05 9807.0 .04 2.80 9~08.05 .01 .20 9809.05 <.01 .20 9810.15 .32 1.00 (g/cc) (%] (%) 2.68 43.20 56.60 2.73 24.90 70.56 2.74 36.40 63.10 2.70 83.80 15.20 2.65 70.80 29.20 2.69 28.90 70.70 2.66 15.20 82.20 2.71 34.50 61.30 2.71 39.20' 59.00 2.70 52.6(} 42.90 2.69 53.50 45.10 2.~3 48.50 51.20 2.70 35.60 59.40 2.61 16.70 81.90 2.66 6.80 91.90 2.69 13.00 83.50 2.69 21.30 70.90 2.70 5.70 94.30 LITHOLOGY/COMMENTS LS- brn-g{y; crpxln; dns; arg; Cbt nod Ls- brn-gry; crpxln; dns; arg Ls- brn-gry; crpxln; dns; arg Ls- gry; crpxln; dns; arg; tr Pyr tr Crin; bioturb Ls- dk bm; crpxln; dns; arg; abd Cbt; crinal; sec Calc in frac Ls- med gry; crpxln; dn$; sl arg; crinal;sec Calc in frac Ls-med gry; crpxln; dns; sl arg; crinal; abd Cbt; sec Calc in frac Ls- grygrn; crpxln; dns; arg; occ glauc sh lam; crinal w/ lg Crin; Chalco~yr; sec Calc in frac Ls- gry~r~; crpxln; dns; arg; occ glauc sh lam; crinal w/ lg Crin; Chalcopyr; sec Calc in frac As- med gry; crpxln; dns; arg; glauc sh lam; crinal Ls- med gry; crpxln; dns; sl arg; glauc sh lam; styl; Ls- med gry; crpxlm~ dns; styl; Chalcopyr UNABLE TO TAKE SAMPLE L$- med 9rY; crpxln; dns; styl; abd Cbt Len Ls- med gry; crpxln; dns; styl; Cht Len Cbt- gry-blugry; hd; frac Cht- gr¥-blu~ry; hd; frac UNABLE TO TAKE SAMPLE Ls- dk gry; crpxln; dns; sh lam; occ Cht nod Ls- med-dk gry: crPxln; dns; sh lam; styl; bioturb Ls- med gry~ crpxln; dns; styl; sl bioturb Ls- med-dk gry; crpxln; dns; styl bioturb; crinal CO~'ENTIONAL CORE ANALYSIS REPORT COMPANY : WELL NAME : FILE NAME : NO. SAMPLE I. D. -- 1 2 2 3 3 4 4 5 5 6 6 7 7 9 9 10 t0 il 12 12 13 13 14 14 15 15 SOHIO ALASKA PETROLEUM CO. SAG DELTA ~ll (CORE ~8) RMD 9 DEPTH - (md) (%) 9817.15 .04 2.70 9818.15 .03 2.00 9819.75 .72 1.30 9~20.8 .01 1.00 9821.95 2.80 2.50 9822.75 .01 3.20 9824.25 1.10 1.30 SATURATION PERMEABILITY POROSITY GRAIN DENSITY WATER OIL (g/cc) (~) (%) 2.~4 52.70 42.60 2.67 54.40 38.30 2.7L 72.70 22.60 2.67 52.00 38.50 2.70 57.20 28.60 2.69 25.80 61.70 2.59 56.70 37.8~ 9825.95 .24 1.00 9826.95 .02 1.40 2.61 69.30 26.90 2.63 66."Z0 27.00 9827.95 ,02 1.BO 9828.95 .02 .24 2.60 93.60 4.65 2.63 98.50 0,00 9B29.95 .0l 1.30 9834,2 .01 3.30 2.70 28.00 62.20 2.72 38.40 48.80 9838.95 9840.9 .02 1.70 2.69 10.20 76.70 2.70 11.00 85.80 LITHOLOGY/COF~ENTS Ls- med gry; crptoxln; dns: sill algal rem Ls- med gry; crptoxln; dns; sil; algal rem Ls- dk gry; crptoxln; dns; frac; sec Cal in frae; sl sil (PLUG FRAC=EI K) Ls- med-dk gry; crptoxln; dns; sl siI; frac Ls-reed gry] crptoxln; d~s; thnly lam; tr Crin (PLUG FRAC=BI K) Ls- med gry; crptoxln; dns; frac; tr Crin Cbt- med gry; d~s; calc; ex frae; sec Cal in fra~; tr ~yd in frac (PLUG FRAC=HI K) Ls- med-dk gry; crpxln; dns; sit; ex frae; Cal in frac; tr ~ydc i~ frac (PLUG FRAC=HI K) Ls- meO-dk gry; ~rpxln; dns; Cbt I.P.; frac I.P.; sec Cal in frac Cbt- it g~Y; dns; si calc; e~tr frae Cbt- med gry; dns; calc; frae; algal rem; foss frags; sec Cal in frac Ls- med gry; crptoxln; dns; algal rem; crinal Ls- med-dk gry; czptoxln; dns; foss; crinal; lg sec Cal xl$ in frac Ls- gry gn; crptoxln; dn$; styl; frae; tr Hydc iu frac Ls- qry gm; c~ptoxln; dns; frac; COMPANY : NELL NAME : PILE NAME : C0~ENTIONAL CORE ANALYSIS REPORT SOHIO ALASKA PETROLEUM CO. SAG DELTA ~11 (CORE 181 RMO 900H No. SAMPLE I.D. 16 16 17 17 18 18 19 19 20 21 21 22 22 23 23 24 24 25 25 26 26 27 27 28 28 29 29 30 30 DEPTH - Crud) (%) 9841.8 .06 1.40 9845.5 .01 1.90 9847.45 .01 3.30 9848.85 .01 2.50 9849.9 .01 1.60 9850.95 .02 2.I0 9852.2 .02 3.00 9852.95 .Ol 2.70 9853.9 '.02 3.10 9854.95 .03 3.10 SATURATION PERMEABILITY POROSITY GRAIN DENSITY WATER 0IL 98.56.9 .03 5.30 9857.95 .01 2.20 9858.9 .10 2.00 9859.7 .07 2.20 9860.9 .SD 2.60 ( g/cc ) (%) 2.70 21.§0 60 2.69 33.70 56.10 2.71 22.10 50.40 2.70 29.10 46.90 2.69 22.70 32.80 2.69 29.50 26.30 2.69 12.10 63.30 2.69 9.30 59.80 2.69 10.20 65.90 2.69 23.30 44.00 2.69 31.10 44.50 2.69 24.70 29.30 2.70 40..50 40.50 2.69 12.80 65.40 2.69 27.10 52.80 LITHOLOGY/CO~ENTS Ls- it brn; crptoxln; dns; styI; tr foss Ls- tn-bu; crptoxln; dns; mnr lam Ls- tn-bu; crptoxln; dns; sl los; tr Pyr Ls- tn-bu; crptoxln; dns; foss; tr algal rem; peld; frac; lg sec Cal xls in frac Ls- tn-bu} crptoxln; dns; foss; tr algal rem; peld~ styl; crinl Ls-tn-bu; crptoxln; dns; peld; crinal; algal rem; tr Glauc Ls- tn-bu; crptoxln; dns; peld; crinal; tr algal rem Ls- tn-bu; crptoxln; dns; peld; crinal; tr algal rem Ls- it bm; crptoxln; dns; peld; cri~al; tr Glauc; frac; sec Cal in frac Ls(Grst)- tn-~u; crptoxln; dns; peld; crinal; hi frac; med-lg sec Cal i~ frac Ls- t~-bu; crptoxln; d.ns; peld; crinal; s%yl; fr&c; sec Ca! in frae Ls- to-bu; crptoxln; dns; paid; crin&l; styI; tr Glauc; tr Pyr; frac Ls- tn-bu; crptoxl~; dns; peld; tr Glauc; frac; tr sec Cal Ls- tn-bu; crptoxln; dns; peld; styI CONVE~TIONAL CORE ANALYSIS REPORT COMPANY : WELL NAME : FILE NAME : SOHIO ~J~ASKA PETROLEUM CO. SAG DELTA ~11 (CO~E ~8} l~ 9O~H No. SAMPLE -- -- 31 31 32 32 33 33 34 34 35 35 36 36 37 37 38 38 39 39 40 40 41 DEPT~ - (mdl (%) 9861.9 .04 2.20 9862.7 .04 3.00 9863.9 .01 3.50 SATURATION PERMEABILITY POROSITY GRAIN DENSITY WATER 0IL 9864.7 .05 4.30 9866.2 .09 4.90 9866.95 .04 3.80 986.7.95 . 03 4.60 9865.9 .01 3.50 9869.7 .01 3.20 9870.9 .07 5.70 9871.6 .08 6.90 {g/col (%) 2.69 24.50 52.60 2.69 24.70 48.00 2.69 10.50 60.80 2.69 I6.80 55.20 2.70 14.90 65.40 2.70 17.50 49.40 2.69 23.90 47.80 2.69 15.60 55.60 2.69 28.50 41.80 2.70 22.20 52.90 2.70 10,60 64.60 LITHOLOGY/COMMENTS Ls- tn-bu~ crptoxln; dns; peld; tr Pyr & Glauc Ls- tn-bu; crptoxln; dns; peld; Foss frags; tr Gtauc Ls- tn-bu; crptoxln; dns; peld; Foss frags; frac& filled w/sec Cal Ls- tn-bu; crptoxln; dns; peld; Foss frags; tr Pyr; mnr Crin Ls- tn-bu; crptoxln; dns; peld; Foss frags; tr Pyr Ls- tn-bu; crptoxln; dns; peld; frac& filled w/sec Cal Ls- tn-bu; crptoxln; dns; peld; styl Ls- tn-bu; crptoxln; dns~ peld; crinal; tr Pyr Ls- tn-bu; crptoxln; dns; petd; crinal; tr Pyr Ls- It brn; crptoxln; dns-sI ea; peld; crinal; tr Pyr; sl Hydc st~ Ls. It brn; crptoxl~; sl ea; pel; crinaI; si Hydc stn; sl P.P. CONVENTIONAL CORE ANALYSIS REPORT COMPANY : WELL NAME : FILE NAME : SOHIO ALASKA PETROL~-~3M CO. SAG DZLTA #11 {CORE #9) RMD 900I No. SAMPLE I.D. DEPTH -- -- -- 15 9-15 10075.9 , 16 9-16 10077.2 SATORATION PERMEABILITY POROSITY GRAI~ DENSITY WATER OIL (md l (%) (g/cc) (%) {%) 3.50 2,13.80 2.81 30.90 27.00 3.50 20.00 2.80 33.50 30.!0 17 9 -17 10077,9 7.10 26.10 2.84 44.70 25.70 18 9-18 10078.9 4.6,0 25.40 2.83 48.80 19.30 19 9-19 20 9-20 21 9-21 22 9-22 23 9-23 24 9-24 25 9-25 10079.9 1.90 19:.50 2.83 49.10 15.50 10080.2 1.00 18~80 2.77 44.60 23.90 10082.3 .01 1.30 2.74 49.00 32.70 10082.9 ,01 1.90 2.74 25.10 11.20 10086.7 .03 1.60 2.64 75.80 16.90 10090.9 ,04 .90 2.70 78.10 11.60 10092.3 .00 20.50 2.82' 17.90 35.80 26 9-26 10093.4 .05 7.40 2.80 25.10 43.90 27 9-27 10094.1 .22 9.30 2.83 41.60 9.30 LITHOLOGY/COMMENTS DO1- It brn; vf xln; ea; sue; si frac; sl Hydc stn; mod interxln pot. Dol- It brn; microxln; sl ea; suc; $1 frac; sec Cal; anhy: sl Hydc stn; mod pot Dol- it bm; microxln; sl ea; sl suc; sl frac} sec Cal; tr Hydc stn; mod pot Dol- it bm; microxln; $1 ea; sl suc; sl frac; sec Cai; tr Hydc stn; mod Dol- tn; microxln; sl ea; sl suc; sty1; v thnly lam; mod-~d.por Dol- tn; microxln; sl ea; ~1 suc; sec Cal; mod por Ls- It gr¥; crptoxln; dns; tr Fo$ frags; sl frac Ls- it gry; crptoxln; dns; tr Fo$ frags; sl fr&c Ls- med gry; crptoxln; dn$; si/; extr frac Ls- med-dk gry; czptoxtn; dns; thnly lam Dol- brn-gry; microxln; mod sl arg; Pyr; si P.P. pot (PLUG FRAC=NO K) Dol- brn-gry; microxln; dns; $1 arg; tr Pyr; sl frac; sec Cal in frac Dol- dk brn gry; microxln; sl arg; sl frac; thnly lam (PLQG FRAC=H/ K) COMPANY : WELL NAME : FILE NAME : No. SAMPLE I.D. DEPTH -- -- -- 9-1 2 9-2 3 9-3 4 9-4 5 9-5 6 9-6 7 9-7 8 9-8 9 9-9 10 9-10 11 9-11 12 9-12 13 9-13 14 9-14 CONVENTIONAL CORE ANALYSIS REPORT SOHIO ALASKA PETROLI~0M CO. SAG DELTA tll {CORE ~9) RMD 900I SATURATION PERMEABILITY POROSITY GRAIN DENSITY WATER OIL {%) (g/ecl (%) (%) 10056.3 10.00 26.00 2.86 32.10 24.30 10058.8 19.00 34.80 2.86 22.70 32.40 10060.9 19.00 31.60 2.85 29.70 29.30 10062.1 12.00 22.70 2.84 15.00 38.00 10063.L 16.00 24.40 2.84 24.20 33.70 10065.1 17.00 27.50 2.84 I7.10 37.80 10066.4 20.00 32.00 2.82 52.80 25.30 10067.3 17.00 22.10 2.85 31.70 36.90 10069.2 8.50 22.70 2.84 38.10 24.80 10070.7 3.70 ,. 11.40 2.81 12.50 40.S0 10072.0 7.70 .50 2.71 , 49.00 32.70 10072.8 .21 .53 2.72 77.90 21.60 10073.9 3.70 16.60 2.82 24.80 31.50 10074.7 4.30 18.10 2.83 27.30 25.40 LI THOLO~Y/COMMENTS Dol- med-dk bra; vf xln; ea; si suc; tr anhy; tr Pyr; Hydc stm; gd interxln pot Dol- med-dk brn; vf xln; ea; sl suc; tr anhy; tr Pyr; Bydc stn; gd interxln pot Dol- med-dk bm; microxln; ea; suc; amhy; tr Pyr; Hydc stn; gd mol pot Dol- med-dk bm; microxl~; ea-sl dns; sl suc; Hydc stn; gd P.P. pot Dol- med bm; microxln; sl dns; $1 suc; Hydc stn; mod P.P. por Dol- med btm; m/croxln; ea; suc; frac; sec Cal in frac; Hydc stn; gd P.P. pot Dol- med-lt bm; microxln; ea; sl suc; anhy; Hyde stn; v gd mol por Ool- med-lt bm; microxln; suc; anhy; ~ydc stn; v gd mol por Dol- It bm; microxln; mod dns; si frac; $1 H~dc stn~ mod Dol- lt-mod bm; mod dns; sl Hyde stn; sl pot L$- it gry; crptoxln; dn$; extr frac (PLUG FRAC=HI K) Ls- It gry; crptoxln; dns~ styl; thnly lam w/Crin along lam; tr pyr Dol- It bm; vf xln; ea; suc; $1 talc; si Hydc stn; mod-gd inter- xln pot ~ol- It bm; vf xln; ea; suc; $1 calc; $1 Hyd~ stn; mod-gd inter- xln pot (PLUG FRAC=HI K) CON%~NTIONAL CORE ANALYSIS REPORT COMPANY : WELL NAME : FILE NAME : No. S~PLE I.D. 4 4 5 5 6 7 7 9 9 10 SOHIO ALASKA PETROLEUM CO. SAG DELTA ~1! (CORE ~1~) RMD 9OOJ SATURATION DEPT~ PERMEABILITY POROSITY GRAIN DENSITY WATER OIL - (md) [%) (g/cci (%) 10095,2 .B2 10097.2 .10 10098.2 .01 10099.1 .01 iOi~i.3 .Oi ,. 16.90 2.83 18.00 41.00 1.10 2.63 5.10 90.80 .Si 2.67 8.70 86.50 10lB1.9 .01 15104.1 .01 1~105.2 .01 10107.5 .~i 10109.2 .44 1,50 2,62 20.58 68.20 ,71 2,61 33,50 65.20 .68 2,71 16,40 82.00 .30 2,69 43.40 40.10 .02 2.70 40,10 42.80 2.00 2.72 12.20 73,10 3.90 2,61 32,80 43,80 LI THOLOGY/C OMMENTS Dol- it brn; microxl~; si ea; sl suc; sl pot Ls- it gry; crptoxln; dns; Cbt I.P.; sl frac Ls- it gry; crptoxln; dn$; extr sil Ls- tm-It gry; crptoxln; dns; Cht I.P. Ls- med gry; crptoxln; d~s; extr sil; frac; sec Cal i~ frac; tr ~ydc sin in frac Ls- dk 9ry; crpxln; dns; sl sil: tr Foss fraqs; frac; tr Hydc stn in frac Ls- dk gry; crpxl~; dns; sl sil; sl arg; frac; Sec Cal i~ frac Ls- dk gry; crpxl.; dns; sl sil~ tr Crib; sl frac Ls- dk gry btm; crptoxln; dns; sl sil; tr Crin; styl Ls- gry brn; crptoxln; dns; sil; Foss frag$ COMPANY WELL NAME FiLE NAME No. SAMPLE I.O. 11 11 12 12 13 13 14 14 15 15 16 16 12 17 CONVENTIONAL CORE ANJ~LYSIS REPORT SOHIO ALASKA PETROLEUM CO. SAG DELTA ~11 (CORE %10) R/ID 900J OEPTH PERMEABILITY - (md) 10110.2 .09 10111.5 .01 10112.1 .08 10113.0 .22 10114.7 .59 10115.8 8.60 10117.0 2.20 SATURATION POROSITY GRAIN DEESITY WATER OIL {%) (g/cc) (%) 4.30 2.72 5.30 68.6~ 4.20 2.72 7.40 57.90 5.40 2.75 4.60 59.90 5.30 2.74 9.10 60.30 10.80 2.68 25.00 52.40 25.80 2.83 64.80 15.00 13.60' 2.69 39.90 32.80 LIT~OLOGY/COMMENTS Ls- dk gry gn; crptoxln; dns; styl; frac Ls- med bm; crptoxln; dns; styl Ls- med bm; crptoxln; dns Ls- med bm; crptoxln; d~s; styl; frae Dol- reed bra; erptoxln; 4ns; Cbt !.Po; $1 Hyde sin Dol- It bm; microxln; si ea; si suc; si pot Dol- ]t bxn-tn; microxln; md dns; $1 ;uc; Ch~ I.P. SOHIO ALASKA PETROLEUM COMPANY 900 EAST BENSON BOULEVARD ANCHORAGE, ALASKA TELEPHONE (907) 561-5111 P.O. BOX 6612 ANCHORAGE, ALASKA 99502-0612 August 28, 1985 Mike Minder State of Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Mr. Minder: Enclosed please find the core summary for Sag Delta 911.~!. The core ships from this well are being sent under separate shipment. Chips from the pressure cored interval are not included, as analysis has not been completed. These chips will be forwarded to you as soon as possible. Also being shipped are core plug ends from L5-24 to serve as core chips from L5-24. I am also forwarding boxes of dry cuttings from Sag 11 and L5-24. Please return the transmittals as you receive the materials. Thank you. ~;pcG 'GeZ;~ces 564-4317 CGZ:dec 2 C t51 V [ O Core 1 Depth 9201-9261 Recovery 60' 10" (99.7%) Description Shale limestone and dolomite: 0-5% porosity, slightly fractured, moderate oil stain ~ 2 9262-9272 10' (100%) Pressure core: limestone, 0-5% porosity, slightly fractured, light oil stain. 9272-9282 10 ' ( 100% ) Pressure Core: shale and limestone: 0-5% porosity, rare fractures, minimal oil stain. 9282-9342 60' (100%) Shale, wackestone, packstone, dolomite: 0-15% porosity, few open and calcareous-filled fractures, bleeding oil, heavy oil stain. 9342-9352 6' 4" (60.3) Pressure core: wackestone and dolomite: 0-5% porosity, few fractures, light oil stain. 9352-9412 60' (100%) Shale, limestone, packstone, grainstone, sandstone: 0-10% porosity, highly fractured intervals, sandstone heavily oil stained. 9412-9472 60' (100%) Packstone, sandstone, wackestone: 0-10% porosity, moderately to highly fractured, bleeding oil. 9472-9531 58' 7" (99.3%) Packstone, grainstone, wackestone, shale: 0-20% porosity, lightly fractured (highly fractured in small intervals), with bleeding oil from fractures. 9730-9789 57.5' (97.3%) -. Limestone, dolomite, wackestone, shale: 0-15% porosity, lightly to moderately fractured, some oil bleeding from fractures, light to heavy oil stain in rock. Alaska Oji & IJas C;o¢~,s, Commission Core 10 Depth 9789-9817 Recovery 27' 5" (98%) Description Wackestone, dolomite, limestone: 0-5% porosity, moderately fractured (open fractures), oil bleeding from fractures. 11 9817-9876 57' (96.6%) Wackestone, mudstone, packstone: 0-5% porosity, moderately to heavily fractured (open and calcite-filled), some oil bleeding from fractures, no other hydrocarbon shows. 10056-10094 39' (100%) Micrite, dolomite, limestone: 5-15% porosity, moderately fractured, moderately oil stained, bleeding oil. 13 10094-10119 25 ' ( 100% ) Wackestone, limestone: 0-5% porosity, lightly fractured, no visible stain or bleeding oil. .). 0..5.8 0. {: 7 U . 27 fAC& !. ,,! i": t4 ? h /,5 e :.i "" h 0.7? ;,i (,. 7'; 1.24 w 1.26 2.0~ t,~ 2.21 2.40 ~ 2,57 1,.9~ %; 2.20 0,03 ~ 0.50 0,97 ~ l,O0 1. 7~ = I. 76 3.32 E 3,53 ,:~, tS ~ 4,21. 4.14 g 4.3q 4,26 F', 4,75 4.50 K 5,08 4.5S E 5.50 5.0? F 6.3~ 5.90 F 7,33 O. ~; 3 'g 7.65 E 9..q9 7.46 F 9.75 7 . ,'%5 K 10.2~ 7,77 F 10,51. 7,'~6 E 10,~7 "1 , %8 ~ 1.1,35 8.26 E 12,63 9.52 ~ J3,99 10,97 ~ !.5,37 :[..3,95 E i7,57 !5.55 K 18,82 17.07 E 19,74 18.4:3 'g 20,46 19,74 E ~.~, 1~ 21.03 E 21,99 ?2.07 ~? 22'b7 ~2,~6 R 23,27 45 52.. 55 59 64 6~ 76 8O 32 39 32 41 5O 1"/ 43 47 4U 5~,00. ~"~ ~' 57 0 n ~ i'", v 59 O, 0, !'~ (:, 60 (,'~ n, f:, C' X' .:', r, .h x' RuSr'tTt':G ?L,F,v'hTION: hiST. ~ E K T ~ Z I F, U 7' 1-1 PF~C '~iN 24,30 25.10 2b.~q 26,46 9'7, ~6 27,9~ 9_, 9.06 30,2 .I 3i 1.94 r-: :1..2n 2.'~'3 S 32,i2 ,~...)7 ~ 33,54 15,7q S ~4,3J 17.4a ~; 35.10 S.':'.~5 F ,75,95 ].9,,~3 S 37'19 ~I,97 .S 39.65 33,4,9 ~ 69 0 ~ 34.5~ S 6R ,13 35,46 S 67 25 E 3~.37 S 67 !4 E 3"/,75 S ~5 20 E 39.2~. S 63 31 40.5~ 8 62 20 g' 42.i4 S 61 56 E 45,33 S 61 0 : 4"!.11 50.7S 52, q~a. 54,37 5t:.24 S 57.77 59,13 60.51 8 60 42 61 , 5q ?9,'?a ,S 5,%.74 E 62,32 29.2c~ ,S 55.54 E 62.79 28.:~3 $ 50.,54 E 63,56 2d.6~. S ~'/.65 w 64'36 2~,S3 .q 58..i9 F 65'08 28.,o5 S ~9.23 F 65,'/~ P9..31, 5 ~0,97 F 66,84 30.25 ..'~ 60,~4 ~ 67,~0 30.30 ~ 60,t2 ~ 67,3~ K 6f, .~v P [. $ ,.--~ ~' ,',~ G 46.15 F'j a0,52 ~' a'!.t9 60,4? E 67.09 a0..35 ~ 6'7.19 ~9.95 F ab.57 ..9.~ ~ 65,8~ 59.32 ~ a5.26 59,~2 E 65.!5 59,37 ~' 65.23 60,u5 F. 64,97 64.33 E 6{t, 74 a5.~3 E 70.01 rq" 9C 'E 72 :~ 4 7 7 O ~ r, K 73 71 D E P' A o. T t_.~ ~ F ~. Z I [,., ,'i T l-T 08 S O5 S 5 7 67 S 72,45 E 75.i~ $ 74:30 E 7.3.,~:3 ,~' 75,86 5 7$ 27 6 74,54 E' 70,73 5 76 16 E ~7o17 E 78.~a $ 77 ~-~t ~ F-,) n SV..{:,"~'iot: S r.., Lri;., ~.~ ,,'fy 4. £. ?5, !£Li.,Y gL:qnT:',~ ~'bF,'~T?,I'Z',]N: 4b. 15 ? i Oq ,q i.'76 F. i.'7~_ o 87 28 g '/F ,,~ 10.97 ~ lb.37 N 45 32 ~: 5a ~', 24.16 E 24.30 ~,; 83 57 ~ ~,3 5 3i.:2P ~ 33..'~8 5 69 6 ~: 20 S ~i.UI ~ 47.11 ~ t,O 30 E "I~ 5 ~4,?a ~ 6'2.~2 S 61 26 C 2 ~,':', ,, 'ii ~- · ~ . ," C ~ ,'; ¢:, . (", ,, !) r:,o !:'; 0.09 {}, 22 0,26 0.35 46.15 PT PEPARTt!~:~ A Z T y 1~ T ~ 0.16 S 2.15 u 2.15 U 2 ~ ~' . ', 3,07 ~ 3.08 t.0'~ :': 4,tG E 4,29 i.Tg :>:: 4.U9 F ~,46 2.63 ~",', 4.37 E 5.i0 3.52 ~: 4.67 E 5.~5 5,,3S ~,,~' 7.;,.;4 E 9.00 5.8q ~,: 7,55 ~: 9.58 r,~.63 ~.; 7.ao F 9.94 7.20 '~,: 7.7~ g ~,0.5~ 7.32 '~',: 7,62 E t0'56 7,9~ ~,~ 7,3g E 9.OS '~:~ 7.76 E I 1,94 '9.90 t'4 8.81 F 1,3'26 !0,50 JU,64 :'.: 13,09 E 17,00 !.0,5't t,.:< I4.66 K 1.8.03 10.3~ '~,:,' !6.2g f'? 1.9,32 'a.,4~, r.: !,7.71, E 20,08 ~.35 ¥. 1.9,04 ~ 20.7~ 7,.~0 ,',: 20,34 g 21.55 5,~r4 ~; 21,53 E 22.31 4,5~ ~,,; 72.4g ~ 22,94 '~ "J ~ ~ t'~ f~l { · ,. ', ~ Ii.' f' ~ ':'~ ,.'!{ ::', -,, ? ? ~ ::- ,., ~ i' ~' t. ," ~''":' (} , ,; ,- c .:~ 'i "::' .'~ 9 ..j .::'. q, 1 q.. .,'.-':~ :1 i '" c .'2....'4 i ¥.. . ..' '.) :-'"; ~- "5 5r: ',..- PAGE 6 n,;.,, ,r, ?.'; 0 ? $ i.,I iR V E Y: 0 '1 - i~l ~ IR - 8 5 ~' .~..: Zrj , I'.' n V $ ~...1 T d E L, E V' ,'~ 'i' I U'N: 46,15 ET S U R -. ,S E/i. o f[; p 'f DEPAP IURF,. 3~17 ~',~' 23.37 1,9F, ;'4 24.85 F 24,92 U.26 ~: 25,33 W. 25,33 1.27 S 25.~6 E 25.89 2,7P $ 26.82 E 26,96 .%,~:}(l, S 27.46 E 27,~1. 6.05 $ 27.~0 E 28.,%5 ~.u,O S 2d,50 'F' 29.60 9,03 ~, 29,38 T 30,74 ~U,;i~ S 30.1,6 F 31,:35 30,9.3 E 32,96 31,57 E 33,99 ~ 2. ,,:i 3 E 35,01 ~ 3,.1, 2 E 35,87 33.89 '¢: 36,97 34.70 E 38,46 35. ~0 E 39'82 36.5? ~ 37./5 ~ 42.86 ?:q .aT ~ .44.44 41,oq F ~7.98 ~. 3 .. 1. ¢~ F 49.89 44:. b.3 T 51.52 46.20 ~ 53,3~ 4'I. b4 ~ ~5,27 4.9. ~5 E 55.99 5U..~ F 5~.40 ~2.03 E 59.77 q3.31 E 61.d7 PAGE 7 46 15 ~' C.: r) 0 I:' 0 "[ i',, .~,. 1',' F S i-I 0 R T. 2,. D E P A P T U R E !? E ? t7 F E ~:: T D E (.; !"~' I N ,"":, ~..') 0 ,, ?)g 30, {:' 0 ':~4 0. t:,..r' 30.34 s -30,")',:% 0,,,, 75, 30.';4 $ 't.,0 O..~[t 3,0~l(3 S i'1 t,'.52 29. i'7 .... .' -. ~. , · ~ ;~ 0,2 ,r.., 27, ~.:i 3 .'!:, © 3 ..... .. 59,..75 g 65.53 5'-,., 70 F 64.93 59.95 E 64.95 ~.0.57 E 65.44 ~:t.ga E 66.64 ~3.~:o E 68.02 45 o t,,!4 ,V ¢,9.3, a 6 (::: .,, 54 E 70.50 68,(1,9 E 71,~2 ~% 9,66.. ~' 73.06 506 5 66 50 ~.,, 567 9 g 5 67 45 E $ 69 42 E S 70 ?9 S 71 27 E $ 72 7,t,37 ? 74.35 73. ,L'.2 F 7',5.57 '73..~; 9 ~ 76.i. 8 75.07 E 77.17 75.57 r 78,Q6 77.17 'C 78.74 5 73 42 ~j :5 75 4 E 8 75 55 ;5 76 37 S 77 4~ g r SUB.~URFACE DIRECTIONAL SURVEY [~UIDANCE [~ONTINUOUS ~"~OOL Company Well Name SOHIO ALASKA PETROLEUM COMPANY . SAGDELTA /~ll~1327'S,NL,316'EWL, S27,TliN,R16E, UPM) Field/Location W. iLCAT~ NORTH SLOP,Ei, ALASKA Job Reference No: 70771 Lo,qaed 8~. MURTLAND Oat__..~e 02- SEPTEMBER-85 Computed 8~. OGDEN SCHLUMBEROER [31 RECT I ONRL SURV E Y COMPRNY SOHIO ,qL_RSKR PETROLEUM COM WELL SRO DELTR uli FIELO WILDCAT COUNTRY USA RUN ONE DATE LO©OEO 07-MAR-SS REFERENCE 000070?'7 SURFACE LOCATION: SOUTH ~-7' SNL, 316' EW-L, S27, TllN, i._~_E, UPM -so -~o -SO -gO - l o .... ~-+.-FT .bN...?..~-.- ::::::::::::::::::::::::::::::::::: ..~.. ~...;...=..~..~_..;...~_.~... :::::.:::Ll::::::T..:: ............. ' .................... '.'"': ......... · ... i...~.....~..~ ...... ~...~ ......... . ..4...-;..~ ....... {,...~-..~.....; .... I ~ - ~ - : : ::::~ .... ~'~'~:~I ..... :':::': .L:~_.i...N...L'.i.:..L.i ....... ~ ....... ~_L.LL...i .... -.i.-~.-~ ...... t..+-..?.-~-.-+-.. ' ...... . ..,.: ::',, -..+.-?--!--i'-t-~-'-r--!-i--+-'-+---+-'-!---!___:__, .... "-' i" ~--~--?"'?"-~ ......... ~'"?-'i ' ~--.?+-~'---{,--.~...~.--~---~ -~---;'"~-'P" '-"~-'-r-+"?'t ...~ ...... :.~..~..:.~.~.._~..L~..:..:..~.I.~.--~ ........ ~ .... i: . i~,. f"f"~ '-i"-~'-'t"::'-l--'!'-'t"f"?-" ' ..... ..... ..::..i'::;::T...';.. i::::::::' :'.;:..;:::::~::: :-:::;:::"!: ........ ~. +..~ ....... ,.-..~ - ~ - : ":'~":"~': - - ' I'- ~ : ' ~ 7 ~ ' i I~ ...-. ~ ~-::: ~.:.~.~..:...:...:..~.I ! i...~ ...... ;...~ .......... - ............ i..i..Li..i =.L..i.:..i .......... ].~ ........ ~ ...... ; ........ ~ ....... ~ ..... .... "T" . · . . VERTICAL PROJECTION 0 0 10 20 NORTH .................... '"' ~ ...... i:..:' LL':' i.::.:.Z: . , .............. ,~ ...... ~ ....... ~ ...... ? .i .... { .... +"'~ ........ ! .......... ~ .... , "T'I'"7"T' 'T'"T"?T' f": ....... t ....... :"T"T"T''r "~ "?"~"] : ..... . ~ . ~ ~ . ~ . . . . : ~ · : : : ~ : - ~ . ~~'"~ , "T' :' '= .... t---~ ...... l ............... ?' ?'T' ~' 1 ...... --: ...... :--= ~ [::~:'-~': ~'~:':' z.. ~ .~ ...... ~...~...~ .... ~..;..... ~.. ~ ..... ~.. ~ . ~ _ ~ ~--; ~ .. ~ - - F ; ~ '"'7 ........... ~ . ~ ..... J ..... ~..$ ......... ~ ........ : = ~ i ........ J . .... , . . _ ~ ..... ~ - . . , .............. ~ ....... } ~ ~ :; i..2._; ........ L..:.:...L..;...:..~ ................. PROJECTION ON VERTICAL PLANE NORTH - SOUTH SCALED IN VERTICAL DEPTHS HORIZ SCALE = 1/ 10 IN/FT ~O~?H 8O 6O 4O ZO -2O -40 SURFACE LOCATION: 27' SNL, 316' EWL, S27. TllN. ' ~, UPM HORIZONTAL PROJECTION REF 00007077! $CRL£ = 1/gO IN/FY . ;. +..~...;...~.... ............. ~...~...~ .......... +...~ ....... ~ ...... ,...,...~...~...:...~...,...~...~.......~ .................... +...~-..~..-+...,..4.-.~ ....... ~..-~..-~--.;-.-~.-4-.-;...* ....... ~..4...~-.***.~..-~ ....... ~-.4.-.~...~--.+~;-.~...;.~.-~.;....-.4--.~-.-**..~*.~.-;..-,...~--.*,.-~ 1 ..; ~ ;: . ~; ..... ~. ;..; ..... ! ~ ......... :..~ ........... ~ ~....~. ~ ...... ~ ........... :,..~ ~ ....... ~..~...:. ~ ....... :..~..~..a...~....~ ........ ~ ....... ~..s...L.~...~..~-+s...~...~...~.-.~.-+..~.-6.~.--~-g-6..~..,~ . , ' · . ~ s T ........~ .............. t ............... T ............... ~ ............. ~.-4 ................. ~ ...... ~-.--~ ..... ~---~ .............. ~...~.-.$.-4 ..... ~. 4- ~ ...... ~-*{ .~a-~..-?-~.-.~...~..4-..~--~...~--+.-] · ' '}· - ........ } ....... * ..... '"'~ ~ ....... ' ..... ~ '" .......... T"'S*'"; ' ~----~"-r-"~'"'~ ....... 7"T *~ ........ ~ ....... T ~ ....... ~ ....... t""f ........ f ........ ~'*";'"~'"T '~'*'T'"'~"~*"g'*'~"~'"T**?'-'T~"T"T ...... ;'"~ ....... ~'"~-*~'"{ ' ~-~ : ~ - -~1 ' ' ' ' ~ ' ' ' ' ..... ' ' ' ' ~ ' : : ' I : ~ ~ , t · ~ ~ ~ ~'~; ~ ..... : '~ ............ : . ~ .... : ~ ........... ~.-.-', ........ ~..~. ~...~.-.~ ~-~ ....... ~...~.-.:...~..-~...L-~..~...h:-..;...~ ....... ~ ~-..~.-: ....... ..... ~ 7 ' ~ ' ".: ~ -' ;'~. ;7.- ' ' ..7;~~~ ~.. '"'Z..: .... :' . -' ~";-: :;".'"7: :...:": ~.:..:.:..;.~..:..t....~..~ '....:..:.L..L.~ ............. . ~; ~..- ;; ~ ;.. : .- .... ::. : :: .::.~ ..:: ..... :.. .: t : . . . ~ . . . . , : : , : · . : .............................................................................................................. ................................ ~ ..4 ........ ~ ...... ~..~....~ ....... z .-.,.-.~ .......... , ...... ~ ...... ~ ....... + ................. . ..................... ~ ................ ~---~--~ ................. ~ ......... t ............ e..-6---! ..... : ................. : .......... ~ ...... ~...:.; ..................... ~ .............. ~ ..........~ ......................... . · ........ . . . - ............... ~ ................................. ............................ . ............................................. ........... ~..: ....................................................... -80 I ' . . : ...... : . . . ' ' ' .... SOUTH ~80 WEST -40 -ZO 0 ZO 40 EAST Suggested form to be inserted in each "Active" well folder to check for timely compliance with our regulations. OPERATOR, WEL AND NUMBER Reports and Materials to be received by: Date Required Date Received Remarks Completion Report , , Samples Mud Log , , Core Chips Core Description Registered Survey Plat Inclination Survey Directional Survey , , Drill Stem Test Reports Production Test Reports Log Run Digitized Data Suggested form to be inserted in each "Active" Well folder to check for timely compliance with our regulations. 0P-ER~T01~, WELL NAl~ A~D NI)I, iBER ~ Reports and Materials to be received by: ~-- ~,8-- Date Required Date Received Remarks Completion Report y~ Well History ~.~ :~ ....... .~ ~-- t0- ~~ , Core Clips : ~> ed Plat Register Survey yes Directional Survey U:.__ nt ~..,...~_~.,~ . . ..... Drill Stem-.Test Rep-::s : ... .. ,.- ..... _.. ~, p~+-~,'~ _?:o uct on ,st ..... ~ ..- .... - ..... ~, ~e~ K~- ,.?¢'--- ~:" ..j ~ .... . ~ _ ~ '~.' M EMORAN L)UM - Stat6 of Alaska ALASYJ~ OIL AND GAS CONSERVATION CObR~'IISSION TO: THRU: FROM: C. V. ¢¢~z.~/terton Chai~" .~.-~ -.. %onn~e Com~ss~oner Bobby Petroleum DATE: April 12, 1985 FILE NO: D.BDF 29 TELEPHONE NO: SUBJECT: Witness Cement Plug Setting for Final P&A of Sohio's Sag Delta #11. _,Fri_da%April 5, 1985: I traveled this date to Sohio's Sag Delta. ~il-to ~i{neS-s the cement plug setting for final P&A of the welibore. Saturdas:,_A_A~ril ¢ 1985: The placementz,, . -4 of plug #1,. fromm 9,320' to ~-,¢-7~-~ ~ ~0O am. The 4~ ~ub-ng was unst,~.ung zrom the 720' in the 7" liner. A 75 sk of 15 8 Baker packer set at ~i was lb/gal slurry (86 ft' then pumpea down the tubing until the cement reached the packer depth. 3The seal assembly was then stun? back in the packer body and 62 ft was squeezed below the packer at a rate of 2 bbl/min with 1!00 psig. The annular preventer was then closed and the seal assembly w§s pulled out of the packer body and the rest of the cement (24 ft. ) was placed on top of the packer · ~ , · - , h ~ sure to keep the cement uszng the hyaraulzc cmoke to .,o~d back pres slurry from ~--tubing. The tubing was thee; pulled up 175' above packe~ and the well was circulated out. The se ond lu was set from 8 745' to 8 560' using 50 sks ~ p g , , · (58 zt ) o~ Czass G cement. Prior to setting this plug a gel ano water spacer plug containing 40 lb/bbl, of gel was spotted from 8,900' to 8,720' to keep the cement plug from slipping downhole. After getting the cement in place the tubing was pulled up to 8,500' and the well was circulated out. Returns showed small amount of cement in approximately 3 to 4 bbls. which was the result of a wiper plug being pumped dow~ tubing to clean same. 3 The third plug was set from 1,994' to 1900' using 50 sks. (48 ft. ) of Cold Set ! cement after spotting a gel and water plug from ~ 225' to ? 000' ~o_is plug was tagged with a wire line and sinker bar at 1,900'. The top plug consisted of 58 sks of Cold Set Ii after the 9 5/8" casing was cut off 50 ft. below ground level. A 10 3/4" wiper plug was pushed down the 13 3/8" casing to the top of the 9 5/8" casing ce~e_~ from falling downho!e stub to prevent the - n~ . I did not witness this plug setting. I spoke with ~,;~mck Scales Sohio drilling foreman la~er and he told me the wellhead was cut off below ground level and a ~" plate was 02-00IA(Rev. 10/79) C. V. Chatterton -2- April 12, 1985 welded on the 20" conductor pipe ~o~ith the abandonment marker post attached. In summary, I witness the plugging and abandonment of the wellboz'e on Sohio's Sag Delta #11. rOE ',~ ~ I) 3- z. 7- ,f '/ os-r-? DST- & q7/,o- ~PTO' io, ~z .. I%zsz.' · '7~'7.'''' ¥7'~ L-Po To~ 2" /.,'.¢~. £/,./,g' ~ Wi," E~4~. Prd X -/vlef"u F_ _ '//~/"//. d ~ T Toe ~17 3 o ' i % -J I"Z. H . CEMENTING SU~Y ,r ~J~ ~.u~ ~o~ MUD WT. DRILLED DEPTH REQUIRED PLUG LENGTH: FROM CALCULATED CEMENT VOLUME: ~, TOTAL 'CEMENT USED WAS WITH OPEN END DRILL PIPE AT PUMPED DATE ___~'" , LAST CASING_ ~ '/ L/,,/~ @ ' HOLE SIZE AHEAD. MIXED A~ND PL%[PED ~.//~'~ ', CIRCULATED BBLS. OF ~ ~} CU. FT. ( , ( sx.) + '). SX.). MIN. PRE-WASH t Z'J- sx. ) OF WITH / 0//~ ~)..~ ~. ADDITIVES. HRS. THICK TIME. BBLS. OF /7,~,/&/~-- STARTED MIXING CEMENT AT ~ ~O ~ HRS. AT A RATE OF ~, l~'' BPM AND OF . , ,~ 7'~ ,~ BPM AND {/()~ --- ORILLPIPE WAS WET/~~AFTER DISPLACING. PULLED PSI. DISPLACED AT A RATE PSI. C.Z.P. AT .~,fj"O HRS. /.~ '' ~ OF PIPE, AND WAS OUT OF CALCULATED CEMENT TOP AT /~POO HRS. PULLED DRILLPIPE TO o · WAIT ON CEb~NT HRS. Attach: Cemen[ers Job Summary Pressure Charts Other Con[rac[or's Job Su~aries SUPERVISOR CEMENTING S UMlw~Y PLUG'JOB WELL RIG MUD WT. DEPTH ., _~, :~ ;~t~Pp~. PURPOSE OF PLUG · CALCULATED CEMENT VOLUME: _ EXCESS, TOTAL C~MENT USED WAS WITH OPEN EN-D DRILL PIPE AT PUMP ED DATE , LAST CASING ' HOLE SIZE -- REQUIRED PLUG LENGTH: FROM ~z~.A-'~ ' UP TO ~~O ( sx.) + ---- ~''~ CU.FT. ( ~-0 SX.). BBLS. OF CIRCULATED / ~ MIN PRE-WASH AHE.~). MIXED AND PLq~fPED PPG DISPLACED CEMENT WITH / ~_~ BBLS. OF CU.FT. ( ~--C~ SX.) OF ADDITIVES HRS. THICK TIME. AT A RATE OF ~- ~--- BPM AND ~:~ BPM AND 1~ DRILLPIPE WAS WET~~TER DISPLACING. PULL~ ~ WAS OUT 0F CALCU~T~ C~ENT TOP AT STARTED MIXING CEMENT AT /-~ 7~ HRS. ~ ~ PSI.- DISPLACED AT A RATE HRS. PULLED DR%LLPIPE TO · WAIT ON CEb~NT HRS. Attach: Cemen[ers Job Summary Pressure Charts Other Con~ractor's Job Summaries SUPERVISOR CEMENTING - PLUG JOB WELL ~ b~GM ~/ DATE RIG ~~ ~ , LAST CASING MUD WT. 9, ~ /~/~ PPG. PURPOSE OF PLUG ~Z~/,~ REQUIRED PLUG LENGTH: FROM ~/~f ' UP TO /~ CALCULATED'CEMENT VOLUME: Z~ CU.FT. ~ -~"'"0 SX.) + .') EXCESS, TOTAL C~-MENT USED WAS ~ ...... CU..FT.__~ ....... WITH OPEN EN-D DRILL PIPE AT ! /?qd ', CIRCULATED PUMPED ~-- BBLS. OF ~ 0 DX.) .' MIN. PRE-WAS AHEAD. MIXED AND PLq~PED cu. ST. ( ~-~ C~MENT, WITH sx. ) os ADDITIV DISPLACED CEMENT WITH HRS. THICK TIME. BBLS. OF 2-'~/~ · STARTED MIXING CEMENT AT ~/OCP HR AT A RATE OF 4, 5 BPM AND OF /~ BPM AND DRILLPIPE WAS WET'AFTER DISPLACING. PULLED AND WAS OUT OF CALCULATED CEMENT TOP AT ' AND HRS. -- PSI. DISPLACED AT A RAT' PSI. C.I.P. AT /~' ~ OF PIPE HRS. PULLED D~ILLPIPE TI . WAtT ON C E~tE] Attach' Cementers Job Su~.~ur. ary Pressure Charts Other Con~ractor's Job Summaries SUPERVISOR SOHIO ALASKA PETROLEUM COMPANY ANCHORAGE, ALASKA TELEPHONE (907) 561-5111 MAIL: POUCH 6-612 ANCHORAGE, ALASKA 99502-0612 April , 1985 Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Attn: Mr. C. V. Chatterton Gentlemen: ~3HIO RESTRICTF.~ WELL SAG DELTA #11 Enclosed in duplicate is Form 10-404, Monthly Report of Drilling and Workover Operations, for the above-named well for the month of March 1985 Very truly yours, R. H. Reiley District Drilling Engineer RHR:IBG:ckg 4385/0044G Enclosure cc: Well File 17 -- . ---. STATE OF ALASKA - ALASKA C __ AND GAS CONSERVATION CO AISSION MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS · Drilling well Workover operation [] 2. Name of operator Sohio Alaska Petroleum Company 3. Address P.O. Box 6-612, Anchorage, Alaska 4. Location of Well at surface 300' EWL, 99502-612 1320' SNL, Sec. 27, TllN, R16E, UPM 5. Elevation in feet (indicate KB, DF, etc.) ~E = 46.65" ~'MSL 6. Lease Designation and Serial No. ADL 363917 7. Permit No. 84-182 8. APl Number 50- 029-21203 9. Unit or Lease Name ADL 363917 10. Well No. Sa~ Delta #1] 1 1. F~ld and Pool Prudhoe Bay Lisburne Pool For the Month of March , 19 85 12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks Depth at month end: 10,400' Footage drilled: 180' 13. Casing or liner run and quantities of cement, results of pressure tests See attached Well History 14. Coring resume and brief description None /',h-;:;.::;.~ 0~¢ .,':; 15. Logs run and depth where run DIL/SP/BHC/GR LDT/CN~/NBT/Te~p/CA~ EPT/GR/CAL DiL/LSS/GR DLL/)~SFL/GR 10,400' to 9,998' 10,400' to 9,998' 10,400' to 9,998' 10,400' to 9,998' 10,400r to 9,998' 10,400' to 9,998' FDC/GR SHDT CBL/VDL/GR/CCL CBL Gyro VSP 10,400' to 9,998' 10,400' to 9.998' 9,998' to 8,600' 10,308' to 9,880' Surface to 10,400' 16. DST data, perforating data, shows of H2S, miscellaneous data DST #4 - Perforated Interval: 10,042' to 10,052' 10,104' to 10,110' 10,252' to 10,262' DST #5 - Perforated Interval: 9,760' to 9,870' DST #6 - Perforated Interval: 9,472' to 9~490' Produced 76 bbls. of fluid at 99% water cut Produced 91 bbls. oil and 178 bbls water Produced 325 bbls water at surf. w/trace oil (CONT. ON REVERSE SIDE) 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. SIGNED~ TITLE~.~~ DATE 4 '~ -- ~ S NOTE--R~equired for each caler~dar month, regardless of the status of operations, and must be filed in duplicate with the Alaska Oil and Gas Conservation Commission by the 15th of the succeeding month, unless otherwise directed· Form 10-404 ~¢~ Submit in duplicate R,~v 7-1-R0c'-./'~ ~f 16. DST #7 - Perforated Interval: 9,231' to 9,254' Reversed out 98.7 bbls. water and 4 bbls oil from test string DST #7B - Perforated Interval:9,231' to 9,254' Riggin% up to perform acid fracturing job 9,310' to 9,320' WELL HISTORY SAG DELTA #11 March 1985 Drilled 6" hole to 10,400'. Ran open hole logs. Ran VSP and gyro. Ran 13 jts. 4 1/2" 12.75# L-80 DSS liner with shoe at 10,400' hanger at 9,893'. Cemented liner with 75 sx Class 'G' cement. Tested casing to 3000 psi. Drilled out landing collar, plugs and cement to 10,310'. Displaced well to 9.6 ppg NaCl. Ran CBL/GR and temperature logs. Ran #4 DST tools; set packer at 9858'. Tested BOPE to 5000 psi. Tested packer and DST string to 3000 psi. Perforated from 10,042' to 10,052, 10,014' to 10,110' and 10,252' to 10,262'. Flowed well. Reversed produced fluids out of DP. POH. Ran and set 7" retainer at 9886'. Tested retainer to 3000 psi. String into retainer and established injection rate. Squeezed 40 cu. ft. Class 'G' cement under retainer. Cleaned out inside liner. Ran GR/CCL. Tested BOPE. Ran #5 DST tools, set packer at 9577'. Perforated from 9870' to 9760'. Performed stimulation with HCL and diverter. Displaced with nitrogen. Flowed well. Shut well in. Lifted well with N2. Shut in well for PBU. Reversed out fluids and filled well with 9.6 ppg brine. POH with DST tools. Ran and set EZ-Drill at 9740'. Squeezed cement to perforations and reversed out drill pipe. Tested BOPE. Ran ~6 DST tools and set packer. Filled string with nitrogen. Perforated from 9472' to 9490'. Injected stimulation fluids with nitrogen. Flowed well. Shut-in well. Reversed out fluids. Ran and set cement retainer at 9460'. Tested casing to 3000 psi. Squeezed 32 cu. ft. Class 'G' cement into perforations and layed 14 cu. ft. cement on top of retainer. Cleaned out cement to 9450'. Ran #7 DST tools and set packer at 9012'. Perforated from 9231' to 9254'. Flowed well. Injected stimulation fluids to formation. Flowed well. Reversed out fluids. POH. Perforated from 9310' to 9320'. Ran FB-1 packer and set at 9120'. Ran 4 1/2" 12.75~ L-80 tubing to 9120'. Landed tubing. Tested tubing to 1000 psi. Nippled down BOPE. Installed and tested tree to 5000 psi. Tested tubing to 5000 psi and annulus to 3000 psi. Pulled plug in XN nipple. Preparing for acid fracturing job. IBG:ckg4885/0044G SOHIO ALASKA PETROLEUM COMPANY 3111 "C" STREET, ANCHORAGE, ALASKA TELEPHONE (907) 561-5111 MAIL: POUCH 6-612 ANCHORAGE, ALASKA 99502-0612 March 5, 1985 Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Attention: Mr. C. V. Chatterton Gent lemen: Well Sag Delta #11 Enclosed in duplicate, is Form 10-404, Monthly Report of Drilling and Workover Operations, for the above named well for the month of February, 1985. RHR/IBG/hh/0219H Enclosure cc: Well File #17 Very truly yours, .:i ~. STATE OF ALASKA ALASKAC AND GAS CONSERVATION CO~ 'ISSION MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS · Drilling well :~ Workover operation [] 2. Name of operator 7. Permit No. Sohio Alaska Petroleum Company 84--t82 3. Address 8. APl Number P.O. BOX 6-612, Anchorage, Alaska 99502--612 50_029_21203 4. Location of Well at surface 300' EWL, 1320' SNL, Sec 27, TIIN, R16E; U~M 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. KBE = 46.65" AMSL ADL 3639_17 9. Unit or Lease Name ADL 363917 10. Well No. Sag Delta #11 11. Field and Pool Prudhoe Bay Lisburne Pool For the Month of February ,19 85 12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks Depth at end of month: 10,220 '~ Footage drilled: 479" + 389? cores ~-;~-~lFi~£) '~;~' .... ' ........ 13. Casing or liner run and quantities of cement, results of pressure tests See attached Well History 14. Coring resume and brief description Core ~6 9352' to 9412' Core #7 9412" to 9472' Core #8 9472' to 9532" Core ~9 9730' to 9789' Core #10 9789' to 9817" Core 911 9817'- to 9876" Core #12 1Q05.6'~ to 10094r Core #13 1Q094" to 10119?' 15. Logs run and depth where run GR - LDT - CAL 9872': to 9164'~ DIL - SP - GR - BHCS 1Q,0_Q2'~ to 9166'"- LDT - CNL - NGT '" to '" LSS - GR '" to '" Prox - ML '" to '" DLL - GR - MSFL '" to FDC --- GR Dipmeter 10.¢ Q02 ': to 9166 '-' '" tO " 6. DST data, perforating data, shows of H2S, miscellaneous data DST #1 - Test interval 9182" to 9352':'---.-No fluid recovery DST #2 - Test interval 9~73Q'" %o 9~976-'.' ' No fluid recovery DST #3 - Test interval 9998" to 10~,119_"- - RecOVered 317 bbls fluid 17. I hereby~F,.~tify that the foregoing is true and correct to the best of my knowledge. -- SIGNE~.~..~ ~ ~,. ~ TITLE Dist. Drlq.~ ~gineer DATE ~OTff--BeOort on this form is required for each calen month, re~ardloss of the status of o~erations, and must be filed in duolicato ~ith the Alaska Oil and Gas Conservation Commission b~ the l[th of the succeedin~ month unless otherwise directed. Form 10~04 Submit in duplicate Bev. 7-~-80 Well History Sag Delta #11 February 1985 RIH with test string to 9342'. Displaced string to N2, set packer. Adjusted N2 pressure. Opened slip joint safety valve for 5 minute flow. Shut-in for 1 hour. Flowed well for 4-1/2 hours. Shut-in for PBU. Reversed out contents of test string. Unseated packer. Pulled test tools. Tested BOPE. Cut cores from 9352' to 9412', 9412' to 9472', and 9472' to 9532'. Drilled 8-1/2" hole to 9730'. Cut cores from 9730' to 9789', 9789' to 9817', 9817' to 9876'. Ran open hole log. Tested BOPE. RIH and positioned DST tools. Set packer. Opened tool for 5 minute flow. shut-in for 1 hour. Opened tool for 4 hours. Shut-in for 6 hour PBU. Released packer. Reversed out contents of test string. Drilled 8-1/2" hole to 10,010'. Ran open hole logs. Ran 33 jts. 7" liner to 9998'. Cemented liner with 623 cu. ft. Class "G" cement with additives. Cleaned out cement to top of liner at 8668'. Tested liner lap to 3000 psig. Cleaned out cement. Tested liner to 3000 psig. Drilled out shoe and 6 ft. new hole; performed leak-off test to 0.6 psi/ft, gradient. Drilled 6" hole to 10,056'. Cut cores from 10,056' to 10,094', and 10,094' to 10,119'. RIH with test tools. Set packer. Pumped 40 bbls. 9.6 ppg brine and injected 15 bbls to formation. Pumped 40 bbls 9.6 ppg brine, 1000 gal NARS-200 and 1000 gal acid. Displaced with diesel. Injected 20 bbls brine and NARS and acid and 10 bbls diesel into formation. Shut-in well. Flowed well. Shut-in for PBU. Unseated packer. Reversed out contents of test string. Pulled test tools. Tested BOPE. Drilled 6" hole to 10,220'. SOHIO ALASKA PETROLEUM COMPANY 3111 "C" STREET, ANCHORAGE, ALASKA TELEPHONE (907) 561-5111 MAIL: POUCH 6-612 ANCHORAGE, ALASKA 99502-0612 March 1, 1985 Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 ATTN: Mr. C. V. Chatterton Gentlemen: Sag Delta #11 Enclosed in triplicate is Form 10-403, Sundry Notices and Reports on Wells, for the above named well. This report gives notice of intent to change plans and run a 4 1/2" liner. If you have any questions, please call Dick Maskell at 564-5551. Very truly yours, H. Reiley District Drilling Engineer Enclosuue RHR: DRM :peh 2288~/0255G cc: R. S. Allan Well File 17 STATE OF ALASKA ALASKA OiL AND GAS CONSERVATION COMMISSION SUNDRY NOTICES AND REPORTS ON WELLS DRILLING WELL COMPLETED WELL [] OTHER [] 2. Name of Operator 7. Permit No. Sohio Alaska Petroleum Company 84-182 3. Address 8. APl Number Pouch 6-612, Anchorage, Alaska 99502 50-029-21203 4. Location of Well At surface: 300' EWL, 1320' SNL, Sec. 5. Elevation in feet (indicate KB, DF, etc.) KBE = 50' AMSL 27, TllN, R16E, UPM 6. Lease Designation and Serial No. ..A~L 363917 9. Unit or Lease Name ADL 363917 10. Well Number Sag Delta #11 11. Field and Pool Prudhoe Bay Lisburne Pool 12. Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations [] 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). The original well plan was to drill 6" hole to +10,800' BKB, run open hole logs and abandon 6" hole with cement plugs. We now propose the following: O O O Drill 6" hole to 10,400' BK3 Run open hole logs Run and cement 4 ½" 12.75 lb/ft L-80 AB DSS liner from 10,400' up to 9,890'. (+110' inside 7" liner shoe). The liner will be cemented with'a low fluid loss Class TG' slurry. Clean out inside liner. Run test tools and perforate 4 ~' liner for production test Dependent on test results, the zone will either be suspended with a packer/tailpipe assembly and a mechanical plug or abandoned by setting a retainer above the top of the liner and squeezing cement through the retainer to cement off the perforated interval. It is anticipated that the liner will be run on or about March 5, 1985. / 14.1 hereby certify that the foregoing is true and correct to the¢ % ~ best of my~/~~l~knowled~l¢~ ~_~i,L;i,U,,~!j.3., A--..-., '.r ' ~1~' Signed ~ Title The space below for Commission use Date Conditions of Approval, if any: Approved by. OltiGIIIAI. SIGIII£1:I eT LON~i[ C: SI~ITil Approved Copy Returne~ By Order of COMMISSIONER the Commission Date Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate SOHIO ALASKA PETROLEUM COMPANY February 3111 "C" STREET, ANCHORAGE, ALASKA TELEPHONE (907) 561-5111 MAIL: POUCH 6-612 ANCHORAGE, ALASKA 99502-0612 , 1985 Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Attn: Mr. C. V. Chatterton Gentlemen: WELL SAG DELTA #11 Enclosed in duplicate is Form 10-404, Monthly Report of Drilling and Work- over Operations, for the above-named well for the month of January 1985. Very truly yours, District Drilling Engineer RHR:IBG:ckg 2685/0044G Enclosure cc: Well File #17 Exploration ...... STATE OF ALASKA ALASKA( . AND GAS CONSERVATION CO AISSION MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS 1. Drilling well [] Workover operation [] 2. Name of operator 7. Permit No. Sohio Alaska Petroleum Company 84-182 3. Address 8. APl Number P.O. Box 6-612, Anchorage, Alaska 99502 50-029-21203 4. Location of Well at surface 300' EWL, 1320' SNL, Sec · 27, TllN, R16E, UPM 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. KBE = 46.65' ~MSL I ADL 363917 9. Unit or Lease Name ADL 363917 10. Well No. Sag Delta #11 11. Field and Pool Prudhoe Bay Lisburne Pool For the Month of. January ,19 85 12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks See attached Well History for detail 13. Casing or liner run and quantities of cement, results of pressure tests See attached Well History for detail 14. Coring resume and brief description Core #1 9201'- 9262' Core #2 9262'- 9272' Core #3 9272'- 9282' Core #4 9282'- 9342' Core #5 9342'- 9352' 15. Logs run and depth where run 17~" Hole; DIL/SP/BHCS/GR 12¼" Hole: DIL/SP/BHCS/GR Surface - 2670' 2684'- 9178' 1 6. DST data, perforating data, shows of H2S, miscellaneous data None 17. I hereby certify that thef~ing is true and correct to the best of my knowledge. NO'I-E-~Report on this form is required for each calehdar month, re§ardless of the status of operations, and must be d in Ouplicate with the Alaska Oil and Gas Conservation Commission by the l~th of the succeeding month, unless otherwise directeO. Form 10-404 Submit in duplicate Rev. 7-1-80 WELL HISTORY SAG DELTA #11 Drilled 26" conductor hole to 73'. Set cellar and 20" conductor. Cemented conductor with 200 sx Cold Set II. Installed and function tested diverter system. Spudded well at 1800 hours, 1/9/85. Drilled 17 1/2" surface hole to 2690'. Ran open hole logs. Ran 66 jts. 13 3/8" 72# L-80 Buttress casing to 2688'. Cemented casing through DP with 3880 cu. ft. Cold Set II. Performed 80 sx Cold Set II top job. Nippled up and tested BOPE, okay (witnessed by B. Foster, AOGCC). Tested casing to 3000 psi, okay. Drilled out float equipment and shoe. Drilled to 2715'; performed leak-off test to 0.614 psi/ft, gradient. Drilled 12 1/4" hole to 9190'. Ran open hole logs. Ran 237 its. 9 5/8" 47# L-80 Buttress casing to 9182'. Cemented with lead slurry of 1250 cu. ft. Class 'G' with Gel and tail slurry of 575 cu. ft. Class 'G' neat. Tested casing to 3000 psi, okay. Installed and tested packoff to 5000 psi. Tested BOPE. Injected conventional mud into 9 5/8" x 13 3/8" annulus. RIH and tagged cement at 9047'. Tested casing to 3000 psi. Downsqueezed the 9 5/8" x 13 3/8" annulus with 282 cu. ft. Cold Set I cement followed by Arctic Pack. Cleaned out cement, float equipment and shoe. Drilled to 9198'; performed leak-off test to 0.7 psi/ft gradient. Cut conventional core #1 from 9201' - 9262'. Cut pressure cores #2 & 3 from 9262' - 9272', and 9272' to 9282' respectively. Cut conventional core #4 from 9282' to 9342', pressure core #5 from 9342' to 9352'. IBG:ckg2685/0044G(3) MEMORANOUM State of Alaska ALASKA Oil/ AND GAS CONSERVATIOI~ CO~-~.~ISSION f~'¥ (/-/ r n / , TO: Co V~.~ to DATE: January 18 Chai~m~ k~, _~_~:{>/ ~,~ ~o: D. BDF. 3 THRU: Lonnie C. Smith Co~i s s ioner FROM: Bobby Foster¥~ ~x '~' - Petroleum Inspector 1985 SUBJECT: Witness BOPE Test on SOHIO's Sag Delta #11, Sec. 27, TllN,R16E,IR,~., Permit No. 84-182. Monday, Januar~ 14, 1985: The BOPE test began at 3:30 am and was conclude8 ac 5:3-0 am. As the attached BOPE test report shows there were no failures. In summary, I witnessed the BOPE test on SOtlIO's Sag Delta #11. Attachment 02-00IA(Rev. 10/79) O&G #4 STATE OF ALASKA ALASKA OIL & GAS CONSERVATION COMMISSION B.O.P.E. Inspection Report Inspecto~/~~~ ~~ ~P,~J~~ 'Operator ~~ ~J~~ - D Location: Sec~ T/t~Rt~EM ~ Drillin~ Contractor~~~'~ Location, General ~ Well Sign~ General Housekeeping~ Rig ~ Reserve Pit ~~ ~ -- Audio Mud Systems Visual Trip Tank Pit Gauge Flow Monitor Gas Detectors Test Pressure BOPE Stack Annular Preventer / Pipe Rams ~ Blind Rams / Choke Line Valves / H.C.R. Valve _~ Kill Line Valves / Check Valve ~ Date W · // Representa/tive ~'~/ ~/~~~ Permit # /~ ~as~ng S~ ~&~ ~. e esenta ve ACCUMULATOR SYSTEM Full Charge Pressure3~P~ ~D psig. Pressure After Closure/3~p psig. Pump incr. clos. pres. 200 psig - Full Charge Pressure Attained: ~ -- N2 ~/~ /~7~ ~.~O~ ~ psig Controls: Master ~.~ Remote~.~ Blinds switch cover ~_~ Kelly and Floor Safety Valves Test Results: Failures Upper Kelly. Lower Kelly Ball Type Inside BOP Test Pressure Test Pressure Test Pressure Test Pressure Choke Manifold~/~ Test Pressure~~ No. Valves /~/ No. flanges ~ ~ Adjustable Chokes / Hvdrauicall~ rated choke Test Time ~ hrs. Repair or Replacement of failed equipment to be made within Commission office notified. mi~ sec. min~O sec. days and Inspector/ Remarks: Distribution orig. - AO&GCC cc - Operator CC - Supervisor SOHIO ALASKA PETROLEUM COMPANY 3111 "C" STREET, ANCHORAGE, ALASKA TELEPHONE (907) 561-5111 MAIL: POUCH 6-612 ANCHORAGE, ALASKA 99502-0612 January 15, 1985 Alaska Oil & Gas Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Attn: Mr. C. V. Chatterton Gentlemen: SAG DELTA ~11 Attached in triplicate, for your review is a Sundry Notice pertaining to a proposed change in second stage cementing operations on the 9 5/8" casing string for Sag Delta ~11. As indicated on the Sundry Notice, it is currently estimated that this operation will take place on approximately 1/21/85. If you have any questions regarding this, please contact Dick Maskell at 564-5551. Yours very truly, , RHR:CRM:ckg 11485/0177G cc: Sag Delta 911 Well File - STATE OF ALASKA ALASKA O,- AND GAS CONSERVATION CO,,,,vllSSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL E~ COMPLETED WELL [] 2. Name of Operator 7. Permit No. Sohio Alaska Petroleum Company 84-182 3. Address 8. APl Number P.O. Box 6-612, Anchorage, Alaska 99502 50-029-21203 4. Location of Well OTHER [] 300' EWL, 1320' WNL, Sec. 27 TllN, R16E 5. Elevation in feet (indicate KB, DF, etc.) 50' AMSL (Est.) 12. I6. Lease Designation and Serial No. ADL 363917 9. Unit or Lease Name ADL 363917 10. Well Number Sag Delta #11 11. Field and Pool Prudhoe Bay Lisburne Pool Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] , Perforations [] 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). Our original proposal for second stage cementing on 9 5/8" casing called for placement of nonfreezing fluid followed by 140 sx Coldset I cement through a DV packer collar placed in the 9 5/8" casing string at +2600' BKB. Because of volume restrictions regarding the size of the reserve pit at the location we would propose to amend procedures for the second stage cementing as follows: After first stage cement job has set up, inject excess mud from pits down 9 5/8" x 13 3/8" annulus. Down squeeze 140 sx of Coldset I cement followed by nonfreezing fluid to surface down the 9 5/8" x 13 3/8" annulus. It is estimated that these operations will take place on approximately 1/21/85. RECEIVED Alaska 0il & Gas Cons. Commissiorl · 14., hel/~ify t~~s tTe a(~c~rlt to the best of my, knowledge. Signed (~) ~k,~_.)~~ ~'~._ Title ~)istrict The spa~l~ ~r C~i~ u~ ~ ~- ~7~~f any: ~pprov~ Co?z, ~ ~;~{~ '~ " By Order of Approved by COMMISSIONER the Commission Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate MEMORANDUM State of Alaska TO: THRU: ALAS¥~_,OIL AI~D GAS CONSERVATION COI, R:IISSION C. ~./~a3~terton DATE: January 15, 1985 Cha~rfi~h~ ,/., ,~.< D. HRH. 4 Lonnie C Smith ' TELEPHONE NO: Commissioner FROM: SUBJECT: HaroId R. Hawkins ,.¢? ~' / ,¢--- . Petroleum Inspector Witness Function Test of Diverter on Sohio Alaska Petroleum Co., Sag Delta Well No. 11, Sec. 27,TllN,R16E,UPM, Permit No. 84-182. Thursday, January i0, 1985: i left ARCO's Well No. IQ-10 KRU, ~ 0'{' an~ih~'~repo~-~ to sag Delta Well No. 11, to inspect and function test the diverter, for Sohio Alaska. The diverter was successfully function tested. In summary., the diverter was function tested and i inspected the diverter lines and valves and found them to be satisfactorily installed. 02-001A(Rev. 10/79) SOHIO ALASKA PETROLEUM COMPANY 3111 "C" STREET, ANCHORAGE, ALASKA TELEPHONE (907) 561-5111 MAIL: POUCH 6-612 ANCHORAGE, ALASKA 99502-0612 -December 10, 1984 Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 995 01 Attn: Mr. C. V. Chatterton Gentlemen: W~ L SAG DELTA $11 Enclosed for your information is a copy of the hydrogen sulfide contingency plan for the above-named well. If you have any questions or comments regarding this plan, please call Dick Maskell at 564-5551. Yours very truly, R. H. Reiley District Drilling Engineer RHR,'.,~: ckg 12784/0095G cc: Sag Delta ~11 Well File RECEIVED Alaska Oil & Ga.s Cons. Commission Anchorage SAG DELTA #11 HYDROGEN SULFIDE CONTINGENCY PLAN TABLE OF CONTENTS Scope .............................. 1 II. Physical Properties - H2S ................... 1 III. Physiological Effects - Hydrogen Sulfide ........... 2 IV. Physical Properties - Sulfur Dioxide ............. 4 Ye Physiological Effects - Sulfur Dioxide ............ 4 VI. H2s Detection/Monitoring and Equipment ............. 5 VII. Personnel Protective Breathing Apparatus ........... 6 VIII. Briefing Areas ........................ 6 IX. Training ........................... 6 Xo H2S Emergency Procedures ................... 7 XI. Special Operations ...................... 10 Appendix A - Emergency Telephone Directory .......... 13 . Scope This contingency plan is prepared to meet the API Recommended Practices for Safe Drilling of Wells Containing Hydrogen Sulfide as stipulated by 20 AAC 25.065(b) of the Alaska Oil & Gas Conservation Commission Regulations. The forecast geology and near by drilling history indicate hydrogen sulfide is highly unlikely to be encountered in quantities dangerous to personnel or equipment. However, since there is no absolute assurance that hydrogen sulfide will not be encountered, the contingency plan provides for early detection and suspension of drilling operations before hydrogen sulfide would be dangerous to personnel or equipment. Further, the plan provides for orderly evacuation of personnel, and protective equipment for those who may be required to shut in the well. Should hydrogen sulfide be encountered, this plan includes comprehensive steps to safely handle the situation. II. Physical Properties - H2S Hydrogen sulfide is a colorless, transparent gas with a characteristic rotten-egg odor. The disagreeable odor of hydrogen sulfide occurs only at relatively low concentrations. Those who have been rendered unconscious from high concentrations and survived, report that they did not notice the so-called rotten-egg odor, but rather that it had a sickening sweet odor. Others reported that the odor was sweet and not unpleasant. Just exactly at what concentration it becomes sweet-smelling is not known, but some believe it is around 500 to 1000 ppm. It should always be borne in mind that some people cannot detect the odor of H2S. H2S is flammable in the range of 4.3 to 45.5 percent in air. A mixture of two volumes H2S and 3 volumes oxygen will explode violently when ignited. H2S has a relative specific gravity of 1.192 (compared to 1.00 for dry air) or a molecular weight of 34.08 as compared to 29 for air. Hence, H2S may be considered heavier than air, and in concentrated form may collect in low places. However, at a concentration of 2000 ppm, which will produce unconsciousness almost immediately, the relative specific gravity or density of the mixture of air and H2S is only 1.003 so that the mixture for all practical purposes has the same density as air. H2S is readily soluble in petroleum hydrocarbons and is soluble in water at room temperatures at the ratio of three volumes H2S for one volume of water. Such things as heating and agitation of the water will reduce the concentration. This solubility and the effect of heat can account, for example, for open drainage ditches evolving dangerous amounts of H2S during the heat of the day in cases where there was no significant amount found during the cool morning hours. Hydrogen Sulfide Contingency Plan Page 2 Information as to the concentrations of H2S that are detectable by smell vary considerably. It is readily detected at about 5 ppm, however, it is generally accepted that concentrations as low as 0.025 ppm are detectable, 0.3 is distinct, 3 to 5 is strong and 20 to 30 ppm is strong but not intolerable. Above 30 ppm the odor does not become more intense as the concentration increases, and above 200 ppm the disagreeable odor appears less intense. These figures are based on initial perceptions. With continous inhalation the odors will appear less, due to olfactory fatigue. It must also be recognized that some other odors will mask even an odor as disagreeable as H2S. For example, the odor of creosols effectively masks the odor of H2S. III. Physiological Effects - Hydrogen Sulfide There are three principal effects from exposure to H2S: 1) the irritant action of high concentrations on mucous membranes, ,2) the effects on the eyes which may result from repeated exposures to low concentrations as well as short exposures to high concentrations, and 3) the more significant effect - paralysis of the respiratory nerve endings from exposure to relatively high concentrations of 500 to 700 ppm or more. Aside from the irritant effects on the eyes, the principal mode of entry into the body is through the lungs. Skin contact, even to high concentrations, is not considered significant. It has been reported that a perforated ear drum can be a route of significant exposure. There is less resistance to outside atmosphere via the perforation than via the breathing apparatus, and therefore, it is reported H2S can be inhaled through the ear under such circumstances. Ear wax and ear plugs offer little protection. Persons seriously exposed to H2S but who recover may suffer some lung irritation which can lead to pulmonary edema or bronchial pneumonia. The systematic effects from absorption of H2S into the blood stream via the lungs is by far the most significant effect. Under normal circumstances, when absorbed into the blood stream, H2S at low concentrations is oxidized rapidly to pharmacologically inert compounds such as thiosulfate or sulfate. When the amount absorbed into the blood stream exceeds that which is readily oxidized, systemic poisoning results in a general action on the nervous system; labored respiration occurs shortly, and respiratory paralysis may follow immediately. Death then occurs from asphyxiation, unless the exposed person is removed immediately to fresh air and breathing is stimulated by artificial respirationbefore heart action has ceased. In high concentrations of gas the mechanics of this respiratory paralysis, formerly thought to involve a chemical reaction with the Hydrogen Sulfide contingency Plan Page 3 respiratory enzymes or with the hemoglobin or both, are now believed to be reflexes resulting from irritation of the carotid sinus. Moderately high concentrations on the other hand cause an arrest of breathing, but not respiratory paralysis, after overstimulation of the respiratory center. In such cases resumption of breathing would probably occur after removal from exposure, even without artificial respiration. Recovery from acute exposure to H2S is usually considered complete, although sometimes prolonged for as much as several weeks, unless there has been damage to the brain due to prolonged oxygen deficiency. Transient and sometimes permanent psychic or nervous changes may be encountered if there has been damage to the brain. It is believed that the presence of alcohol in the blood potentiates the effects of H2S in acute poisoning cases. Those recovering from acute poisoning and who have had alcohol during the past 24 hours reportedly become quite violent. In cases of chronic, or perhaps more properly named sub-acute exposures, symptoms that occur include headache, dizziness, excitement, nausea or gastrointestinal disturbances, dryness and sensation of pain of the nose, throat and chest, and coughing. The following indicated responses to various concentrations of H2S in the atmosphere: PHYSIOLOGICAL RESPONSE TO VARIOUS CI)NCE~RATIONS OF HYDROGEN SULFIDE Response Maximum acceptable concentration for prolonged exposure. (TLV)* Minimum concentration causing eye irritation Minimum concentration causing lung irritation Slight symptoms after several hours Maximum concentration for 1 hour exposure without serious consequences Dangerous after 1/2 hour to 1 hour exposure Pulmonary edema or bronchial pneumonia from prolonged exposure Rapidly produces unconsciousness, cessation of respiration and death Concentration PPM 10 10 Moderately above 20 70 - 150 170 - 300 400 - 700 250 - 600 700 - 900 Hydrogen Sulfide Contingency Plan Page 4 Unconsciousness at once, with early cessation of respiration anddeath in a few minutes 1000 - 2000 *TLV - Threshold Limit Value Eyes can be affected by H2S exposure. It is believed that the effect on the eyes is due to the caustic action of sodium sulfide formed by interaction of the H2S and the alkali of the cells in the presence of moisture in the eyes. Symptoms and effects of exposure to the eyes that have been reported include blurred vision, as though viewing objects through a silk screen; appearance of colored rings around street or other lamps, car lights which appear to be dumbell-shaped, blurred and surrounded by colored halos; red and inflamed eyes, somewhat resembling the "pink eye", and there may be a gritty feeling. There may be intense aching of the eyes, and the eyelids may go into spasms and are difficult to open. These symptoms may disappear overnight or may persist into the next day. Hydrogen sulfide may have a slight anesthetic effect on the eyes, as often the symptoms do not occur until the 2nd to 4th day of exposure. Estimates of minimum concentrations of H2S required to cause eye effects are reported as ranging from 4 to 25 ppm. IV. Physical Properties - Sulfur Dioxide Sulfur dioxide is colorless gas or liquid. It has a pungent odor and is not flammable. It is formed when hydrogen sulfide is burned. The relative specific gravity of the vapor is 2.264 (compared to 1.00 for dry air). Anhydrous sulfur dioxide is non-corrosive to steel or other commonly used metals. In moist environments, it combines with water to form sulfurous acid, but it only very slowly oxidizes to sulfuric acid. In the presence of water, sulfur dioxide is corrosive to steel and other metals. Concentrations of 6 to 12 ppm cause immediate irritation of the nose and throat. A level of 0.3 to 1 ppm can be detected by the average individual possibly by taste rather than by the sense of smell. V. Physiological Effects - Sulfur Dioxide Sulfur dioxide is intensely irritating to the eyes, throat and upper respiratory system. Its irritant properties are due to the rapidity with which it forms sulfurous acid on contact with moist membranes. An estimated 90 percent of all S02 inhaled is absorbed in the upper respiratory passages with only slight penetration in the lower respiratory tract. Hydrogen Sulfide Contingency Plan Page 5 Sulfur dioxide exerts its toxic influence on humans through acute and possible chronic effects. Acute symptoms of exposure are eye, mucosal and upper respiratory irritation. Potential chronic effects include nasopharangit i s, reduction of pulmonary function and increased resistance to air flow. Chronic effects of sulfur dioxide exposure may result from repeated bronchoconstriction. While bronchoconstriction is not itself a chronic effect, it is believed that continual exposure can lead to substantial permanent pulmonary impairment in excess of the normal gradual decrease in pulmonary function due to the aging process. There are only limited epidemiological studies and a few animal studies which attempt to uncover any chronic effects due to sulfur dioxide exposure. Generally, the results indicate the possibility of permanent effects from continuous or long-term exposure but are inconclusive. This material is so irritating that it provides its own warning of toxic concentrations. The TLV is 5 ppm. Fifty to 100 ppm is considered to be the maximum permissible concentration for exposure of 30 to 60 minutes; 400 to 500 ppm is immediately dangerous to life. VI. H2S Detection/Monitoring and Misc. Equipment A. Although hydrogen sulfide is not expected, monitoring is needed to alert personnel immediately to the presence of hydrogen sulfide in the event it is encountered. To provide the necessary warning, Exlog Mud Logging will furnish 5 General Monitor H2S detectors which are capable of detecting 5 ppm H2S in the air. The five monitors will be placed at the shale shaker, pit room, bell nipple, in the cellar and on the rig floor. In addition, an H2S Mud Duck sensor will be placed in the flow line exit. this unit will measure total soluble sulfides, mud pH and the H2S hazard potential. Warning lights and alarms will alert all crews if any of the detectors sense any H2S. B. One portable Draeger gas detector with H2S tubes and one portable Gastech H2S monitor will be available for spot-checking of H2S. C. A supply of Zinc Carb 4151 (100% zinc carbonate) will be available in Deadhorse in sufficient quantity to treat the entire mud system with 2 LBS per barrel in the event the mud becomes contaminated with sulfides. D. Below the protective casing, daily mud checks will be made to determine the presence of sulfides in the mud using a Garrett Gas Train. Hydrogen Sulfide Contingency Plan Page 6 E. Two signs warning of the possibility of encountering H2S will be displayed on location. One at the entrance of the rig, the other at the entrance to the pad. F. In the even H2S conditions necessitate the need for additional equipment, the following will be immediately available at East Dock: 30 - Scott IIA 30 minute units 3 - Cascade air bottlemanifold breathing systems with hoses and Scott IIAPak for total of 12 personnel 1 - High stage breathing air compressor 220/440 VAC G. Well Site Communication - Portable two-way radios will be provided on location in order to permit rapid communication between supervisory personnel in case of an emergency. H. "Danger - Hydrogen Sulfide - H2S" signs will be displayed whenever hydrogen sulfide level is above 10 ppm outside of the rig floor, mud pit or shale shaker areas. Each sign shall have a minimum width of eight feet and a minimum height of four feet and shall be painted a high-visibility yellow color with black lettering of a minimum of 12 inches in height. I. All signs shall be illuminated under conditions of poor visibility and at night when in use. VII. Personnel Protective Breathing Apparatus Six Scott IIA 30 minute, self-contained, pressure demand, air breathing apparatuses will be available on the rig for each member of the drilling crew on duty. Two additional Scott IIA units will be located in the camp. Eight Five minute egress air packs will also be available on the rig for other personnel on the rig. VIII. Briefing Areas T~D briefing areas will be designated at each location. The Sohio Drilling Superintendent on location will designate which briefing area is to be used depending on wind direction. IX. Training A. Self-contained breathing apparatus: Personnel who may be required to use self-contained breathing apparatus in the event hydrogen sulfide is encountered shall be trained in the use of proper maintenance of breathing apparatus. Allpersonnel shall be trained in use and proper maintenance of Hydrogen Sulfide Contingency Plan Page 7 Scott IIA air breathing apparatus or equivalent. Personnel will be required at least weekly to don this equipment to assure understanding in how to use it properly. A written record of this training will be kept. B. Hydrogen Sulfide Detection Equipment Personnel required to operate permanent or portable monitoring equipment will be trained in the proper use and maintenance of units. C. Evacuation Procedures Ail personnel will be advised of evacuation procedures, alarms, reporting areas and steps to take in the event of a hydrogen sulfide emergency. Training will be provided permanent personnel to assure effective operation of evacuation equipment and understanding of evacuation procedures. D. First-Aid Course Ail personnel in the drilling crews shall be trained in basic first aid. E. Safety Meetings Safety meetings will be held at least weekly. These meetings will include review of hydrogen sulfide hazards, warning systems, location of safe briefing areas and training sessions on equipment. Records of attendance will be maintained in the drilling facility. F. No Smoking Areas where smoking is permitted will be established and identified. Should an alert be called, smoking shall not be permitted during the alert. All personnel shall be informed of no smoking areas and regulation pertaining to smoking. X. H2S Emergency Procedures A. If at any time as much as 10 ppm of H2S is detected, the following steps willbe taken: 1. The person detecting the H2S must immediately notify the Driller. He must then notify the Sohio Drilling Supervisor and contract Toolpusher. Hydrogen Sulfide Contingency Plan Page 8 The Sohio Drilling Supervisor and contract Toolpusher will bring portable gas detectors to the rig floor in order to find the source of H2S. 2. Upon notification of the emergency, the Driller will shut down mud pumps and continue to rotate the drill pipe. 3. The rig floor and supervisory personnel will immediately put on breathing apparatus. All other personnel will immediately leave the area and go to the upwind briefing or other safe area. 4. The contract Toolpusher will alert all personnel on location that an H2S emergency exists. 5. The Mud Engineer will run a sulfide determination on the flowline mud. 6. A maximum effort must be made by supervising personnel to resolve the cause of the H2S and to suppress the H2S as quickly as possible. Drilling must not proceed until the cause of the H2S is determined and the well is circulated. Rig floor and mud pit personnel will keep breathing equipment on while monitoring this circulation. 7. The contract Toolpusher will make sure all nonessential personnel are out of the potential danger area, i.e., mud pit area, mudlogger unit, mud storage room, etc. All persons who remain in the potential danger areas must utilize the "buddy system". 8. The Sohio Drilling Supervisor in charge will notify the Sohio Drilling Superintendent of current conditions and actions taken. 9. The Sohio Drilling Supervisor will see that all monitoring devices are functioning properly and reading accurately and will increase gas monitoring activities with portable Drager units. 10. The Sohio Drilling Supervisor will notify all approaching vehicles and helicopters to stay upwind and to be prepared to evacuate nonessential personnel. 11. The Sohio Drilling Supervisor will alert the Deadhorse dispatcher to assure continuous radio watch. The Alaska Oil and Gas Conservation Commission must be notified within 24 hours. Hydrogen Sulfide Contingency Plan Page 9 B. If the H2S concentration exceeds 20 ppm (from an increase gas cut mud) and the well is not attempting to flow, the following steps will be taken: 1. The person detecting the H2S must immediately notify the Driller. He must then notify the Sohio Drilling Supervisor and contract Toolpusher. 2. Driller will shut down mud pumps and continue to rotate drill pipe. 3. The rig floor and supervisory personnel will immediately put on air breathing units. Any other personnel in the high concentration area should hold their breath and evacuate to a safe area. 4. Once air breathing equipment is on, the Driller should: a. Stop rotary. b. Pick up kelly above rotary table. c. Be ready to close the BOP's if necessary. d. If well control problems develop, shut in the well. 5. The contract Toolpusher will alert all personnel on location that an H2S emergency exists. 6. All personnel not listed above must report to the upwind safe briefing area for further instructions from the off-duty Driller. If you are located on the downwind side of the rig when the alarm is sounded, hold your breath and proceed to the upwind safe briefing area. 7. Always put on a portable air breathing mask before proceeding to assist one affected by the gas and utilize the "buddy system". If the affected person is stricken in a high concentrated area, put on a safety belt with 50 feet of tail line and obtain standby assistance before entering the area. Always use the "buddy system" when entering possible contaminated areas. 8. The Sohio Drilling Supervisor in charge will notify all approaching vehicles and helicopters to stay upwind and to be prepared to evacuate nonessential personnel. Hydrogen Sulfide Contingency Plan Page 10 9. Notify East Dock Supervisor to alert heliport and establish 24-hour watch. Notify appropriate state agencies. 10. DO NOT PANIC C. The Sohio Drilling Supervisor and contract Toolpusher will assess the situation and assign duties to each person to bring the situation under control. When the severity of the situation has been determined, all persons will be advised. The Sohio Drilling Supervisor and contract Toolpusher will: 1, Direct corrective action. 2. Notify the Sohio Drilling Superintendent in Anchorage on action being taken. XI. Special Operations A, Coring: During drilling operations below surface casing, it may be decided to core, which takes on critical complexities if attempting to do so in a sour well. Specific coring procedures will be issued for cutting cores. The following practices should be followed during coring operations: 1. After a core has been cut, circulate bottoms up and monitor mud for H2S. If coring rate indicates a porous zone has been cut, put breathing equipment on 30 minutes before bottoms up reaches surface. 2. Unless hole conditions (and/or H2S detectors) indicate extreme conditions, put on breathing equipment 10 stands before core barrel reaches the surface. If worse conditions are suspected or the H2S detector reaches 20 ppm, breathing equipment should be put on earlier. Breathing equipment should be worn by all personnel in the area while the core barrel is pulled, broken out and opened. Portable manual gas detectors should be used to monitor for H2S around the core barrel. When these detectors indicate a safe atmosphere, the breathing equipment can be removed. 3. The following practices should be followed on every core barrel pulled: a. Due to the difficulty in communicating with breathing equipment on, it is required that a chalk board and chalk or note pads be provided during coring operations. Hydrogen Sulfide Contingency Plan Page 11 b. The importance of leaving the breathing equipment on must be stressed to personnel connected with the coring operation. The most critical moment is when the core barrel is opened up. c. Ail personnel on site not wearing breathing apparatus should stay a safe distance upwind from core barrel. d. The cores to be transported must be sealed and marked for the presence of H2S. B. Well Testing 1. Well testing must be performed with the minimum of personnel required in the immediate vicinity of the rig floor and test equipment to safely and adequately perform the test and to adequately maintain equipment and service. 2. Prior to initiation of the test, special safety meetings must be conducted for all personnel who will be on the site during the test, with particular emphasis on use of personnel safety equipment, first aid procedures, and the H2S contingency plan. 3. During the test, the use of H2S detection equipment should be intensified. All produced gasses whould be vented and burned through a flare system equipped with continuous pilot and automatic igniter. Back-up ignition for each flare should be provided. Produced fluids which are stored should be vented through the flare system. C. Well Control: (See drilling program) D. Lost Circulation: (See drilling program) E. Partial Evacuation: When drilling in areas prone to H2S, particularly during critical operations, the Sohio Drilling Superintendent and the contractor's Tool pusher should develop evacuation plans. The plans should be continuously updated as conditions change. When it becomes required to partially evacuate the site, refer to the list of key personnel to remain on site. Hydrogen Sulfide Contingency Plan Page 12 F. Movinq Off Location & Igniting Well: In the event of severe well control problems, the final decision to ignite the well is the ultimate responsibility of the Sohio Alaska Petroleum Company President or Vice President, Operations and Engineering. This decision should be made only as a last resort in situations where it is clear that: 1. Human life and property are endangered. 2. There is no hope of controlling the blowout under the prevailing conditions at the well. Remember, if the well is ignited, the burning H2S will be converted into sulfur dioxide (S02) which is also highly toxic and heavier than air. Hence, do not assume the area is safe after the well is ignited. Any equipment used for evacuation must move upwind of the well. G. Methods of Ignition: 1' The primary method of ignition will be a 12 gauge meter type flare gun. This flare should be fired regularly to insure that the flares and the gun are operating properly. This gun has a range of about 500 feet. Always ignite the well from upwind and do not approach the well any closer than is necessary. Remember, before firing the flare gun or igniting flammable material, check the atmosphere or your location with an explosimeter for combustible gasses. 2. If the above method of ignition fails, or well conditions are such that a safer or better method is apparent, then an alternate should be used. CRM:ckg 103084 APPENDIX A EMERGENCY TELEPHONE DIRECTORY 1. Communications Personnel - Sohio Prudhoe Communications ...... 695-4223 2. Sohio Drilling Personnel - Rose .................. 344-4965 3. Rig Drilling Personnel ................... To Be Determined 4. Regulatory Agencies - Alaska Oil & Gas Commission ...... (907) 279-1433 5. Support Personnel - Medical Sohio ................. 659-4315 Helicopters Air Logistics ........... 659-2221 6. List of Key Personnel R. A. Jones P. J. Martin G. N. Nelson B. L. Rose Manager Drilling Vice President, Operations & Engineering President District Drilling Superintendent 7. Esse International - H2S Safety Contractor ......... To Be Determined October 10, 1984 b~r R H. Reilev District Drilling Engineer Sohio Alaska Petroleum Company P. O. Box 6612 ~uchorage, Alaska 99502-0612 Re: Sag Delta No. 1! Sohio Alaska Petroleum Corapany Peri. it No. 84-182 Sur. Loc. 300'EWL, !320'S~rL, Sec. 27, TI!I'~., R16E, UPM. Btmhote Loc. S A M E. Dear '~ ~r. Reiley : This letter replaces the cover letter dated October 9, ~.984 which was attached to the Sag Delta Mo. 11 application for Permit to Drill or Deepen. Enclosed is the approved application for pe~it to drill the above referenced well. There is evidence that hydrogen sulfide (H2S) gas may be encountered in the dril!~ng and testing of"the~l,isburne Group. o ~= before ~enetration of ~h~ _~zobu_~ro_e in the dri~ ~ip~, of this well and during the testing, the operator shall comply with the minimtt~ requirements for detection monitoring, contingency and control of H2S gas as specified ip 20 JJIC 25.056(c). If coring is conducted, a one cubic inch chip from each foot of recovered core is required. Samples of well cuttings, a minimum of four tablespoons, and a mud log are required. An inclination survey is required as per 20 AAC 25.050(b)(5). If available, a tape ~onta~nzng the digitized log information shall be submitted on all logs for copying except e×perimental logs, velocity surveys and d~ometer surveys Many rivers in Alaska and their drainage systems have been classified as important for the spawning or migration of anadromous~~={sh. Opera~ions_ in these areas are subject to AS 16.05.870 and the regulations promulgated thereunder (Title 5, Alaska Administrative Code). Prior to commencing operations you ~,.._r. ~ H Rei!~v Sag Delta No. !i -2- October 1.0, 1984 may Be contacted by the Habitat Coordinator's Of fine, Department of Fish and Game. Pollution of any waters of the State is prohibited by AS 46, Chapter 3, Article 7 and the regulations promulgated thereunder (Title 18, Alaska Admin~_strative Code, Chapter 70) and by the Federal Water Pollution Control Act, as amended. Prior to commencing operations you may be contacted by a representative of the Department of Environmental Conservation. To aid us in scheduling field work, please notify this office 24 hours prior to commencing installation of the blowout prevention equipment so that a representative of the Commission may be present to witness testing of the equipment before the surface casing shoe is. drilled. %?nero a diverter system is required, please also notify this office 24 hours prior to commencing equipment installation so ~ha~ the Co~mnission may witness test~ng b~ore drilling below the shoe of the conductor pipe. In the event of suspension or abandonment, please give this office adequate advance notificstion so that we may hav~. a ~.~itness present. Very truly yours, : /~ _' ~ ': :_~_..' / ~: ............ .: x...-:i~~ ._~_ ......... ::~ "Lonnie C. Smfth Comm.~is s loner of Alaska Oil and Gas Consolation Co~ission BY ORDER OF Enclosure cc- Department of Fish & Game, Habitat S~ction w/o encl Department of Environmental Conservation w/o encl. SOHIO ALASKA PETROLEUM COMPANY 3111 "C" STREET, ANCHORAGE, ALASKA TELEPHONE (907) 561-5111 MAIL: POUCH 6-612 ANCHORAGE, ALASKA 99502-0612 October 3, 19 84 · .a~aska O±l & Gas Conse. m'ation Commission 3001 ?orct~ine Dr±ye Anchorage, Alaska 99501 Attn: Mr. C. V. Chatterton Gentlemen: W~I.T. Sag Delta #11 Enclosed are the follc~ing documents, in triplicate, along with our check for $100 to cover the permit filing fee. 1. Application for Permit to Drill; 2. Proposed drilling program outline; 3. Proposed Blowout Prevention Diagram & Surface Diverter System; 4. Surveyor' s Plat showing well location. If you have any questions, please call Dick Maskell at 564-5551. Very truly yours, District Drilling Engineer cc: Well File #17 C_.fla.r' "Cornmi:::sJon STATE OF ALASKA ALASKA ~ ,L AND GAS CONSERVATION CO.,,MISSION PERMIT TO DRILL 20 AAC 25.005 la. Type of work. DRILL REDRILL DEEPEN lb. Type of well 2. Name of operator Sohio Alaska Petroleum Company 3. Address P. O. Box 6-612, Anchorage, Alaska 99502 EXPLORATORY [] DEVELOPMENT OIL [] DEVELOPMENT GAS [] SERVICE [] STRATIGRAPHIC L~ SINGLE ZONE [] Delineation MULTIPLE ZONE [] 4. Location of well at surface 300' EWL, 1320' SNL, Sec. 27, TllN, R16E, UPM At top of proposed producing interval (Target: -9160 'ss) 300' EWL, 1320' SNL, Sec. 27, TllN, R16E, UPM At total depth VERTICAL WELL 5. Elevation in feet (indicate KB, DF etc.) I 6. Lease designation and serial no. Est. KBE = 50' AMSL I ADL 363917 12. Bond information (see 20 AAC 25.025) Type Blanket surety and/or number Safeco Ins. 2975387 9. Unit or lease name ADL 36 3917 10. Well number Sag Delta #11 11. Field and pool Prudhoe Bay Lisburne Pool Amount $200,000.00 13. Distance and direction from nearest town NE of Deadhorse - 13 miles 16. Proposed depth (MD & TVD) 11000 ' BKB feet 14. Distance to nearest property or lease line 300' East of ADL 28342 feet ]/. i~umDer oTacres is ease 1280 19. If deviated (see 20 AAC 25.050) 120. Anticipated pressures KICK OFF POINT N/A feet. MAXIMUM HOLEANGLEN/A°I(see20AAC25'035(c)(2) 15. Distance to nearest drilling or completed ,Nell Delta State ~2 - 18. Approximate spud date 10192 fe~t / Ja~._u~_ry 1, 19 85 /~ 3~(J psig@___ Surface I 5720 psig@ 11000 ft. ~ (TVD~S 21 Proposed Casing, Liner and Cementing Program SIZE CASING AND [INER SETTING DEPTH QUANTITY OF CEMEN1 Hole I Casing Weight Grade Coupling Length MD TOP TVD MD BOTTOMTVD (include stage data) ~ 110 8 cu.yds, concrete 26 20 133~ K-55 Bu~_. 80 Surface ll01 2670 3500 cu.ft.Permafrost 17½ 13 3/8 72¢ L-80 Butt. 2670 Surfkce 2670I 12¼ , 9 5/8 47# I L-80 Butt. 9100 Surface 9100l 9100 1200 cu.ft. Class G; ii I 130 cu. ft.Permafrost I I I I 10000 245 cu.ft Class G 8½ i 7 29#~ L-80 Butt. 1400 8600 ~, 8600 , 10000~ .. 22. Describe proposed program: with 18% salt See proposed Drilling and Completion Program attached. Alaska Oii& Ga.s Cons. Comm]ssi'0~ 23. I hereby certify that the foregoing ja'dCE'~nd correct to the best of my knowledge ~ __~ f / (~ District Drilling Engineer The space below CONDITIONS OF APPROVAL Samples required ! Mud log required Directional Survey required [~,YES []NO ! .~YES []NO []YES J~,NO APl number 50-O ~ 'i' Permit number I Appr~g~k. date APPROVEDBY~ ~// Form 1 0~01 Rev, 7-1-80 SEE COVER LETTER FOR OTHER REQUIREMENTS ,COMMISSIONER DATE October 9, 1984 by order of the Commission Submit in triplicate PROPOSED DRILLING PROGRAM SAG DELTA %11 Install and cement 20" 133% K-55 conductor from 80' BGL to surface. Install 20" x 2000 psi diverter system and function test same. Drill 17 1/2" hole vertically t© 2700' and run open hole logs. Run and cement 13 3/8" 72% L-80 buttress casing to surface. Nipple down diverter and install 13 5/8" x 5000 psi blowout preventer stack consisting of 2 sets of pipe rams, one set of blind rams and an annular preventer. Drill 12 1/4" hole vertically to 9100' BKB and run open hole logs. Run 9 5/8" 47% L-80 buttress casing from surface to 9100' and cement in two stages. The first stage will place Class 'G' cement around the shoe and the second stage will place nonfreezing fluid followed by permafrost cement in the 13 3/8" x 9 5/8" annulus displaced through a DV packer collar set approximately 100' inside the 13 3/8" shoe. Drill and core 8 1/2" hole to 10,000' BKB. Run open hole logs. Run 7" 29% L-80 buttress casing from 10,000' to 8600' BKB and cement using Class 'G' cement with 18% salt. Drill and core 6" hole vertically to 11,000' BKB running one open hole drill stem test if justified by shows. Run open hole logs. Abandon 6" open hole with cement inside 7" shoe. Run cased hole drill stem tests and through tubing production tests in the 7" liner as required dependent on shows. Complete the well with tubing for a long term production test after the rig has been removed. At the conclusion of testing operations the well will be suspended in accordance with applicable state regulations. CRM:ckg 92584 B.O.P. STACK 1:5 5/8" CONFIGUR ~TION TRIPLE RAM STACK 5000 PSI WP DRILLING ANNULAR PREVENTER PIPE RAMS BLIND RAMS CHECK KILL UNE HAND GATE GATE DRILLING SPOOL PIPE RAMS 4" CHOKE LINE HAND GATE HYDR. ASS'T. GATE 20" 2000 PSI WP A/~TO'h4R PREVENTOR 10 3/4" Hydra~c 10" - DIVERTER ~UND LEVE~ ~ff DRILLING SPOOL 20" CONDUCTOR PIPE NOTE: . . Alasi~. . Oil & ~,.~' ...... C~)r~, IJ(~flIrNis~O~ DIVERTER LINE HAS TWO DIRECTION DISCHARGE CAPABILITY AFTER LEAVING RIG SUB-BASES. SURFAr"E HOLE DIVERTER SYSTEM Two.lines ventin9 90° apart --- 10 3/4" manual butterfly valves 1. Ail pipe connections 150t ANSI FI anges or we] ded connections. 2. Manual 10 3/4" butterfly valves, safety wired in open l~sitJon at diverter line tee. ~ 10 3/4" 55~ Buttress 10-3/4" Hydraulic operated Butterfly valve automatically ~ 20" Diverter Spool w/10 3/4" ~ Side Outlet. PROCEDURE ' -- 4~ Rig up diverter system consisting of 20" 2000 psi annular preventer with auxiliary equipment as shown on the diverter drawing. Connect opening side of hydraulic control for 10 3/4" butterfly to annular preventer closing line for simultaneous operation. Test operatoin after installa- tion. Lay dual diverter lines to reserve pit taking into account prevailing wiDds. Open one valve on the reserved pit "tee" to vent flow depending on wind direction. Note: One "tee" valve to be open at all times. In the event of well flow: a) While drilling, lift Kelly above 20" annular. While tripping, install dri.llpipe safety valve (inside BOP). b) Close 20" annular. c) Pick up Kelly in tripping situation. d) Watch wind direction and adjust reserve pit "tee" as required. e) Pump mud slowly through bit to avoid plugging or freezing. f) After need for diverter has passed, purge line with steam or air. NOIr: ~Be 10 3/4" hydraulic controlled butterfly valve, at diverter spool, opens by hydraulic line connected to 'the 20" annular closing line. ~nis autoraatically opens the valve as the annular preventer closes. T_IIN. T.~)N. dO$~4 Howe I$1ond L~T. 70 '~¢ '$G. 4~u Z O~t~. I~B° O$ ° $9. ~ 7~ " 19 21 ~ 2:5 WELL SITE (SEE DET.)4 .J ...... 29 ~"' -.:::-:;.~ ..:..: ~ ~ ~[R T/FI~ TI OF ~ ~RY~ YOR . '~ ~T~' ~1 ~ ~'~' ~ '-~--~G.---- -- ~'LT~i i LL -- ---- ! gocaltat w~h m.' SEE. ~Z, r/1,</, R ~ E , u, ff /,4 7' ,'V'~_~/p~ul PYlUDItO~ OFFI~ :3C-PT I~, ly84 CHECK LIST FOR NEW WELL PERMITS IT EM APPROVE DATE Company :~ ~"~ Lease & Well No. 7 YES NO REMARKS (1) Fee (2) Loc thru 8) Ad '(8:%"' (3) rain ('/P'~-,./~" ?~ ¥-~ 1. Is the permit fee attached ......................................... 2. Is well to be.located in a defined pool ............................ 3. Is well located proper distance from property line .................. : -- 4. Is well located proper distance from other wells ................... 5. Is sufficient undedicated acreage available in this pool ........... 6. Is well to be deviated and is well bore plat included ............... ~_~_ 7. Is operator the only affected party ................................ ] 5(_~/~.~ 8. Can permit be approved before ten-day wait . e (9' thru 11) 10. XZl (10 a. nd 11) (4) Casg ~1,,~ /t~-J--2~ 12. 2 th"~u 20) 13. 14. 15. 16. 17. 18. 19. 20. Does operator have a bond in force .................................. ~g--x. Is a conservation order needed ...................................... Is administrative approval needed ................................... Is conductor string provided ........................................ Is enough cement used to circulate on conductor and surface Will cement tie in surface and intermediate or production strings ... Will cement cover all known productive horizons ..................... Will surface casing protect fresh water zones ....................... Will all casing give adequate safety in collapse, tension and burst.. Is this well to be kicked off from an existing wellbore ............. Is old wellbore abandonment procedure included on 10-403 ............ Is adequate well bore separation proposed ........................... .~--~__ (5) BOPE (21 thru 24) 21. 22. 23. 24. Is a diverter system required ....................................... ~o*~ __ Are necessary diagrams of diverter and BOP equipment attached ....... ~ Does BOPE have sufficient pressure rating - Test to ~/Z~Zrg> psig/~-~ ., Does the choke manifold comply w/API RP-53 (Feb. 78) .................. (6) Add: ~ I~-f. gq 25. Additional requirements ............................................. Additional Remarks: ~Z H 0 ¢./3 ~ ~Z. Geology: .E.ngineering: HWK~~ LCS: BEW ~ WVA JrT HJ~ y~g JAL _. ~ / rev: 12/08/83 6.CKLT INITIAL GEO. UNIT ON/OFF POOL CLASS STATUS AREA NO. SHORE Well Histo.ry File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information, of this nature is accumulated at the end of the file under APPENDIX. .. No special 'effort has been made to chronologically organize this category of information. .o v"--'R,i=iC~tTI~N,_ , LiSTiNC, :1-' ;;-' T & P '- SEXY'ICE NAME :EDIT OAT- : 3~13IN :FS1A S'3~TiNO~TION ~ :O1 ~R': Vi O'J$ T ~, ~' E ': ~'O,4'.~ENT$,.. , -. :;::',: FILE HEADER :Y<: FILE N&M,= :EDIT .031 SERVICE NA'qE : VEtS!ON :~ : D~TE : MAXIMtJM LEqGTH : 102_4 FILE T~PE : PR~VIOOS FiLE : ;',':;:': IN=ORMATIJ"i' ~,ECOROS :k"' YIN E,,! CO',ITENTS PRES: E OMMENTS -: ..... mETROL:UM ZOMPAN'Y JNIT JNIT TYPE OOj O'DO 000 O'OO 003 TYPI~ O0 0 3OO 000 gO0 C ,.t,T E SI ZE 0.30 012 OO4 012 0O5 003 SiZ: 001 CODE 055 365 065 O 65 0,55 055 0,55 065 C !3 0 E:_" 0 5 5 tV~ OlO.~Ol V~RI~I~aTIJ~ LiSTIN3 D~SE f ;:~ SCM' d,~ERG-R :i,.. ZC'.JNTY ST&TE ......... THIS · ,. .,..,..,..,.., ..... :.- ~.%-.,.-'- ::~ J.OB HLJM'5-F_R ~T LOP: L. SU]NEY TYPE FLJID ~n~ ~iSTTy VZSSOSiTY ~LJI9 LOSS = 2O.O00"S 104' - SIT SIZE = 17.5" = 3:)UD MUD = ,3.9 L',S/S R~t = 3.530 B 63.0 = ~B.O S R'4F = 2.830 D 53.9 = 9.0 '~'4~ = 2.950 ~ 63.3 = 15.~ C3 R~ ~T ~MT = 3.157 ~ '7!,.0 JOB NU~'!OER &T ~CC: 70253 RUN ~2, DATE LDSG'iS: 23 J,~,W 85 LV~ OlO.WO£ VE~I~IC&TiD~ LISTIN~ P&SE ~ JOB NUMBER AT LDo: J. KO,RING TYPE FLJIO DENSITY VZSSOSITY FLJID LDSS ~tAT~ZX LZMESTONE JCB ~LIXl LO~ CAS TYP '9 1:34 ' ~CC: 70257 LO3'gE3: 15 FEB = BLAND = 9.5 : ~7.0 S : ~.5 33 9153' NUqS'ER AT ACC: 70258 ~5, DATE LOGGED: 4 MAR 55 : J. KOHRINS lNG = 7.003" ~ E FLJID : DISPERSED 9'998 ' BIT S~'ZE. 3tT SZZ= = 17.5" = 12.23" SiZE : 8.5" T3 RMC 5HT. - BIT S'IZ~ : 6" Ti] TJ Z598' TO 917~' = 2.330 = 2. = 1.BT0 : 54.0 64.3 142. 10402' D= D= D~ = 1.505 D 74 DF = 2.593 @ 74 DF = 2.252 @ 7~ DF = .7559 @ 155 DF LV? OiO.q02 VERIFIC~TI,2'~ L=STtN3 PA$E ~ Vi$SOS:TY = 45.3 S :LJiJ L355 = 5.2 23 ~aT~ZX .iM~STSW~ 2~ = !.02 ~MF = '3.77 ~MC = 1.39 IM A~ ~WT = 3.411 :,, 72 ~ 72 O,= -D 1~9 OF LOGS IN'LUD:D ~'TH T~!S MAGN:TIC TAP:: -Ti]~t SP-tF'RIS~LLY F]CgSED L3G (DIL) ;~V~iLAB_E: 10:+29' TS 37" ERGE] @ ~995', 9160', ER'SE] "$ ~9,59', ~144'~ 3OMPE,~S~I'ED ' 33 (BHC) &V~!LA:SLF: 10425 ' =RGE] ~ 9969',~ 7144', & 2645' ERGE3 ~D ~952', 9161'~ & :2640' SONIC LOS AVAILABLe: 10422' TO 9148' M~SROLO$ LV) OIO.M02 ¥~iF'C~Ti3~ L!STIN3 PASE 5 ]AT.~ &V&iL,&B_~: 104Z5' T3 MER3E3 ~ 10030' DjAL LATE~LO~ (CLL) 3~T& AVAiLABlE: 10435' T3 5~ ~V~iL~BLE: 10~25' T3 ~SFL MER3ED 9 9~$9' LLD,LLS,-&LI ME~SE3 ¢ 9974' :3RqaTiSN 35qSITY CSq~ENS~TE3 LDS D&T~ AV~iLA~_'E: 10415' T3 =~2~, qERSEO ~ 13000' 3~ q'-gG=3 ~ 9983' LITM] 35NSITf COM~ENS&TE2 L3~ CLOT) C3Mm~S,&TEO qEUTR]N L3G (LDT) ]aT& AV&iLAS' E: 10~1~' LDT/'NL ~I'-RG=3 9 13200' SSR '4ERS=D @ 9955' NATURAL 3&MM& TDO. (~3T) DAT~ Av'&iLABLE: 1041~' NGT qE'RS50 @ 9965' ELEST~OM~3NETIC P~OPA3&TIDN f30t DATA AVaiLABLE: 10408' 9198 ' 9150' 9979 ' ] N L ¥ 9131' T] 913'5' T3 ONLY) LV= O!D.~O~ VE~iRIS~TIG~ LISTiN3 P~GE 5 ENTRY Ty'~2 3 15 3ATJ~ SPECIF!CATI3N 5LO"KS MN='4 SSRVi~E SERVICE JNIT SFLU DIL ILD 3IL ]-iMM iLq DIL SP DIL SR OIL 9T ~HC jS/F 3R ~dC G,~PZ 3R FDN ~i CALl ~DN ?HS~ ;DN S/C3 DRqS FDN SG~ LDT ~PI 3&LI LDT RHgB LDT ~/03 DRY3 LDT 3/C3 NR ~f L3T RNR& L3T NPqI L3T' ~j P E: L 3 T ~CqL LDT C~S FC~L LOT PRDX P'RX J~MM ~tN3R PRX 3qMM Mi~V oRX 34MM CAL~~ P~X MS =L DLL O iMM LLQ QLL 3tMM LLS DLL 31MM SP DLL S A L I D L L ! GR LSS G~Pi SIZE 1 t 1 1 &P'Z AP1 AP1 L,SG TYPE ~L&S,S O0 000 O0 O0 220 O1 O0 120 O0 120 O0 010 O1 O0 310 O1 O0 520 80 O0 310 01 O0 3,10 O0 2;3'0 O1 O0 350 02 O0 355 O0 310 O1 O0 280 O0 35~ 02 O0 356 O1 O0 ~20 O1 00 000 O0 O0 890 O0 30 358 O0 3,30 31 O0 330 30 O0 2'70 30 O0 252 03 O0 250 O0 O0 2,80 O0 310 O0 270 O0 220 10 O0 220 09 O0 010 01 O0 280 91 O0 310 01 R - o '~ C 33_-- ,55 73, 55 56 qOD '~J. 3 0 0 O 0 O O 3 0 0 0 3 0 0 0 0 O 0 0 0 D 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 ,~ 0 0 0 0 0 0 0 ENTRY 53 PROCESS (OCTAL) 00000000000000 00000030000000 00000030000000 O000000000000O 00300300000000 03000000030000 03000000300000 O000000000OO00 00300000000000 00000000000000 00000000000000 O3000OO0000000 OOO00OO0000030 00000000000000 O0000000000000 O0000ODO000000 00300000000000 00000000000000 00000000000000 OOO0000'OOO0000 O0000O90000000 00000000000000 OOO00OO0000000 O000000000OO00 00000000000000 O000000OOOOO00 OOO000OOOgO000 O00000000OO000 O0000000000000 O000000000OO00 00300000000000 03000000000000 LV~ 019.H02 VERZFiC;TZCq L.ZSTiN3 P2GE 3T LSS JS/F O0 520 80 0 3T~ LSS JS/F ,30 52'3 83 3 TPL 5PT qS/M 03 132 01 0 E~TT :~T O~/M gO 130 O! 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