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100-035
STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1 a. Well Status: Oil ❑ Gas ❑ SPLUG ❑ Other ❑ Abandoned ] Suspended❑ 20AAC2510V 20AAC 25.110 GINJ ❑ WINJ ❑ WAG❑ WDSPL ❑ No. of Completions: 1b. Well Class: Development ❑ Exploratory ❑ Service ❑ Stratigraphic Test ❑ 2. Operator Name: g oC 6. Date Comp., Susp., or Aband.: Ld(p 14. Permit to Drill Number / Sundry: kivoi+ G d 3. Address: a3 7 Dale Spudded st 10 15. API Number. 50- 0-7,-b - 20006 - ob 4a. Location of Well (Governmental Section): Surface: Im' fSL *e `77%t Ve -k30LAA Top of Productive Interval: r `�^171a Total Depth: A p� •v 1 8. Da a TD Reached: 16. Well Name and Number: Vkr7' s 12 9. Ref Elevations: KB: 2 f,' GL: 4t BF: 17. Field / Pool(s): Fh.k f-if,V 10. Plug Bade Depth MD/TVD: 4n - 18. Property Designation 4b. Location of Well (State Base Plane Coordinates, NAD 27): Surface: x- V15, 2W y- 61,305"300 Zone- (0 TPI: x- y- Zone- Total Depth: x- y- Zone- 11 Total Depth MD/TVD: 22$5 1?t 19. DNR Approval Number. 12. SSSV Depth MDfTVD: go� X)KA 20. Thickness of Permafrost MD1TVD: 5. Directional or Inclination Survey: Yes U (attached) No Submit electronic and printed Information per 20 AAC 25.050 13. Water Depth, if Offshore: (ft MSL) 21. Re-drip/Lateral Top Window MDtTVD: 22. Logs Obtained: List all logs run and, pursuant to AS 31.05.030 and 20 AAC 25.071, submit all electronic data and printed logs within 90 days of completion, suspension, or abandonment, whichever occurs first. Types of logs to be listed include, but are not limited to: mud log, spontaneous potential, gamma ray, caliper, resistivity, porosity, magnetic resonance, dipmeter, formation tester, temperature, cement evaluation, casing collar locator, jewelry, and perforation record. Acronyms may be used. Attach a separate page if necessary 23. CASING, LINER AND CEMENTING RECORD WT. PER GRADE SETTING DEPTH MD SETTING DEPTH TVD AMOUNT CASING FT TOP BOTTOM TOP BOTTOM HBO-L_E`SIZE CEMENTING RECORD PULLED ` {.D` i6o, n O -Sk 1067' V4 -314 Airso %X s, "n 19%4' g' n -'s 24. Open to production or injection? Yes No If Yes, list each interval open (MD(IVD of Top and Bottom; Perforation Size and Number; Date Perfd): 25. TUBING RECORD SIZE DEPTH SET (MD) PACKER SET (MDlTVD) Z - 71g„ -5 � 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. Was hydraulic fracturing used during completion? Yes L No Per 20 AAC 25.283 (1)(2) attach electronic and printed information DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED rloK6 27. PRODUCTION TEST Date First Production Moo- ('s� Method of Operation (Flowing, gas lift, etc.): Date of Test: tt�211J!iif Hours Tested: Production for Test Period ♦ Oct -Bbl: Gas -MCF: Water -Bbl: Choke Size: Gas -Oil Ratio: Flow Tubing Press. Casing Press: Calculated 24 -Hour Rate Oil-Bbt: Gas -MCF: Water -Bbl: Oil Gravity - API (cor): N A Form 10-407 Revised 512017 CONTINUED ON PAGE 2 Submit ORIGINIAL only 28. CORE DATA Conventional Core(s): Yes ❑ No ❑ Sidewall Cores: Yes ❑ No ❑ If Yes, list formations and intervals cored (MD/TVD, From/To), and summarize lithology and presence of oil, gas or water (submit separate pages with this form, if needed). Submit detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results per 20 AAC 25.071. NONE 29. GEOLOGIC MARKERS (List all formations and markers encountered): 30. FORMATION TESTS NAME MD TVD Well tested? Yes ❑ No ❑ If yes, list intervals and formations tested, briefly summarizing test results. Permafrost - Top Permafrost - Base Attach separate pages to this form, if needed, and submit detailed test Top of Productive Interval information, including reports, per 20 AAC 25.071. Formation at total depth: 31. List of Attachments: NONE Information to be attached includes, but is not limited to: summary of daily operations, wellbore schematic, directional or inclination survey, core analysis, paleontological report, production or well test results, per 20 AAC 25.070. 32. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Joe Ramirez Authorized Name: Joe Ramirez Contact Name: Authorized Title: Division Program Manager NSB Dept. of Public Works Contact Email: Joe.ramlrez no -s ope.org Authorized R" 10-10-1 7 Contact Phone: 907-852-0489 Signature: Date: � INSTRUCTIONS General: This form and the required attachments provide a complete and concise record for each well drilled in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. All laboratory analytical reports regarding samples or tests from a well must be submitted to the AOGCC, no matter when the analyses are conducted. Item 1 a: Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 1 b: Well Class - Service wells: Gas Injection, Water Injection, Water -Alternating -Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Item 4b: TPI (Top of Producing Interval). Item 9: The Kelly Bushing, Ground Level, and Base Flange elevations in feet above Mean Sea Level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 15: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). Item 19: Report the Division of Oil & Gas / Division of Mining Land and Water: Plan of Operations (LO/Region YY -123), Land Use Permit (LAS 12345), and/or Easement (ADL 123456) number. Item 20: Report measured depth and true vertical thickness of permafrost. Provide MD and TVD for the top and base of permafrost in Box 29. Item 22: Review the reporting requirements of 20 AAC 25.071 and, pursuant to AS 31.05.030, submit all electronic data and printed logs within 90 days of completion, suspension, or abandonment, whichever occurs first. Item 23: Attached supplemental records should show the details of any multiple stage cementing and the location of the cementing tool. Item 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, or Other (explain). Item 28: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Pursuant to 20 AAC 25.071, submit detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results, including, but not limited to: porosity, permeability, fluid saturation, fluid composition, fluid fluorescence, vitrinite reflectance, geochemical, or paleontology. Item 30: Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Item 31: Pursuant to 20 AAC 25.070, attach to this form: well schematic diagram, summary of daily well operations, directional or inclination survey, and other tests as required including, but not limited to: core analysis, paleontological report, production or well test results. Form 10-407 Revised 5/2017 Submit ORIGINAL Only NORTH SLOPE BOROUGH DEPARTMENT OF PUBLIC WORKS P.O. Box 350 Barrow, Alaska 99723 Phone: 907-852-0489 Scott K. Danner, Director TO: GUY SCHWARTZ, SENIOR PETROLEUM ENGINEER ALASKA OIL AND GAS CONSERVATION COMMISSION 333 WEST 7TH AVENUE ANCHORAGE, ALASKA 99501 FROM: JOE RAMIREZ, DIVISION PROGRAM MANAGER NORTH SLOPE BOROUGH DEPARTMENT OF PUBLIC WORKS DATE: OCTOBER 10, 2019 SUBJECT: NSB 10-407 WELL COMPLETION REPORTS SB 12 AND SB 18 Mr. Schwartz, Regarding the list of 20 producing wells the AOGCC provided with the July 2, 2019 notification letter, it was found in the opinion of the Borough, that two wells known as South Barrow 12, and South Barrow 18 which are referenced as suspended have been plugged and abandoned (P&A) since 1988. The Borough Department of Public Works has researched a history of documents in an effort to demonstrate that wells #12 and #18 were plugged and abandoned. To recap what we have found: • The AOGCC was notified by the Borough of its intent to P&A well #12 on March 10, 1988. The AOGCC provided sundry approval on March 16, 1988 as approval #8-164. The Borough had Halliburton circulate permafrost cement down the annulus to surface. The annulus and bullhead were closed. The wellhead was removed, the pipe cut off below ground level and a dry -hole marker installed. • June 22, 1988: The AOGCC's Doug Amos wrote he was unable to complete inspections on both wells #12 and #18 due to snow cover. He did comment that both marker posts for wells #12 and #18 were in compliance, and provided a location clearance inspection form for both wells. • August 16, 1988. Amos again travelled to Barrow. He wrote the pad was still in need of gravel, the pad lower than the marker post area. On September 22, 1988 Amos wrote that final approval for well #12 was pending the Borough a barrel around a marker, and grade the pad. • October 11, 1988: The Borough notified the AOGCC that the well sites in question to include wells #12 and #18 were graded to AOGCC specifications and photographs were provided. On October 20, 1988 the AOGCC provided final location clearance for well #12. While information for SB 12 was fairly well documented, the Borough during its research was unable to locate significant documentation regarding the history of SB18. The requested form 10-407 Well Completion reports are attached. Please contact me at Joe. Ramirez@north-slope.org, if you have any questions. Respectfully, %e Ra dwj Joe Ramirez, Division Program Manager Department of Public Works Attachments: Attachment 1 — SB12 Well Completion Report Site photos Location Clearance Inspection Surface Abandonment Report Application for Sundry Approval Wellhead schematic Attachment 2 - SB18 Well Completion Report Cc: Scott K. Danner, Director Department of Public Works Allen Snow, Division Manager Fuels and Natural Gas Page 2 of 2 WELL / O 2— CONTRA OR REMARKS a FIELD- DISTRICT - STATE OPERATION AT REPORT TIME J/i�LL VL1IYI�L a1.�.1 Ua�1 DAYS DATE v /6 /�k ❑ CHECK THIS 13LOCK IF SUMMARY CONTINUED ON BACK Weather Temp. Chill Factor Visibility Wind Vel. Signed �A Report OF OF miles knots hA Ai-.._ Schwartz, Guy L (CED) From: Schwartz, Guy L (CED) Sent: Wednesday, September 11, 2019 11:04 AM To: Erik Opstad Cc: allen.snow@north-slope.org; Joe.Ramirez@north-slope.org; Guhl, Meredith D (CED) Subject: RE: South Barrow 18 P & A (PTD 100-046) Erik, I am cc'ing NSB managers from the public works division. If you do find any wellwork files (downhole or otherwise) for SB -18 please direct it to both NSB and myself. Anything that can document the volumes of cement pumped in well SB -18 to P &A will be very useful. Allen/Joe: Please put together a 10-407 report form for each well (SB -12 and SB -18) to the best of your ability with the information you have. AOGCC requires this form to complete the well status change to full P & A. The site clearance that was done for the two wells back in 1988 does not relieve the NSB of its obligation to fill out 10-407 forms and document the downhole plugging of the wells. Without this form the wells will continue to be on AOGCC's list of wells requiring bonding. Regards, Guy Schwartz Sr. Petroleum Engineer AOGCC 907-301-4533 cell 907-793-1226 office CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Guy Schwartz at (907-793-1226 ) or (Guy.schwartz@alaska.gov). From: Erik Opstad <erik.opstad@gmail.com> Sent: Tuesday, September 10, 2019 3:40 PM To: Schwartz, Guy L (CED) <guy.schwartz@alaska.gov> Subject: RE: South Barrow 18 P & A (PTD 100-046) Hello Guy, The Barrow Gas Field days were many moons ago for sure! I'll be back in Anchorage Friday and I'll see what I can find in my historical electronic files from that project. I Please standby! Erik From: Schwartz, Guy L (CED) <guy.schwartz@alaska.gov> Sent: Tuesday, September 10, 2019 3:15 PM To: Erik Opstad <erik.opstad@gmail.com> Subject: South Barrow 18 P & A (PTD 100-046) Erik, As we discussed ..do you have any information on the P & A of SB -18 back in April of 1988? North Slope Borough doesn't have any wellwork details in their files either. We never got a 10-407 report with the cement pumping details. We have work details on South Barrow 12 (attached) which was done about the same time so there should be something like this for SB -18 out there. Guy Schwartz Sr. Petroleum Engineer AOGCC 907-301-4533 cell 907-793-1226 office CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Guy Schwartz at (907-793-1226) or (Guy.schwartz@alaska.g_ov). i i� AND GAS CONSERVATION CKA OMAIISSIIOON April 14, 2000 Mr. George Finlayson North Slope Borough P.B. Box 709 Barrow. AK 99723 TONYKNOWLES, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 Subject: Plug and Abandonment Well Completion Form 10-407 Permit: 100-026, S. Barrow #4 Permit: 100-030, S. Barrow #7 - P t(A- 6?r�+uas bei s r ckcd • cfne Hc. ! g - o� 5 Permit: 100-035, S. Barrow #12 Permit: 100-046, S. Barrow #18 Dear Mr. Finlayson: While doing a computer database check of well status, our well files are incomplete. In checking well status, production reports and the well file, the listed wells completion reports (10-407) and daily well operations, have not been received by the Commission to date. We noticed that correspondence referring to site clearance final approval by the Commission was sent to the operator in 1988 for well S. Barrow #12. These materials are required within thirty days after the abandonment of the well under our current regulations 20 AAC 25.070(3). This statement has been in our regulations since 1986. Please provide the completion report and daily well operations for the four wells as soon as reasonable. May 30, 2000? Sinc Robert N. Christenson, P.E. Chairman Cc: Each well file NORTH SLOPE BOROUGH DEPARTMENT OF PUBLIC WORKS P.O. Box 350 Barrow, Alaska 99723 Phone: 907-852-0489 Scott K. Danner, Director TO: JODY COLOMBIE ALASKA OIL AND GAS CONSERVATION COMMISSION 333 WEST 7TH AVENUE ANCHORAGE, ALASKA 99501 FROM: JOE RAMIREZ, DIVISION PROGRAM MANAGER NORTH SLOPE BOROUGH DEPARTMENT OF PUBLIC WORKS DATE: SEPTEMBER 9, 2019 SUBJECT: AOGCC NOTICE DATED JULY 2, 2019 REQUEST TO REVIEW WELL #12 AND #18 STATUS Ms. Colombie, Regarding the AOGCC Notice dated July 2, 2019 requiring of the Borough an increased Bond amount for 20 permitted wellheads in the Barrow Gas Fields, we wish to update. Presently Borough personnel are in the process of review with its insurance provider to establish a Bond or other acceptable form of bonding instrument. It is anticipated the Borough will have some form of surety available for AOGCC acceptance soon. Regarding the list of 20 producing wells the AOGCC provided with the July 2 notification letter, it is found that two wells known as South Barrow #12, and South Barrow #18 which are referenced as suspended, were plugged and abandoned (P&A) in 1988. Please find attached a history of documents that demonstrate that well #12 was plugged and abandoned. Note while well #18 was completed in the same time period, Borough historical records unfortunately are absent similar documents found for well #12, however well #18 is referenced in AOGCC field notes for well #12 as meeting the same requirements. The AOGCC was notified by the Borough of its intent to P&A well #12 on March 10, 1988. The AOGCC provided sundry approval on March 16, 1988 as approval #8-164.Borough contractor Halliburton circulated permafrost cement down the annulus to surface. The annulus and bullhead were closed. The wellhead was removed, the pipe cut off below ground level and a dry -hole marker installed. On June 14, 1988, the AOGCC's Doug Amos inspected P&A of well #12 and did not recommend approval in his surface abandonment report due to a "Clean up after snow is gone" requirement. (Trash & debris) another concern of Amos was that the gravel pad needed to be smoothed. June 22, 1988: Amos wrote he was unable to complete inspections on both wells #12 and #18 due to snow cover. He did comment that both marker posts for wells #12 and #18 were in compliance, and provided a location clearance inspection form for both wells. August 16, 1988. Amos again travelled to Barrow. He wrote the pad was still in need of gravel, the pad lower than the marker post area. On September 22, 1988 Amos wrote that final approval for well #12 was pending the Borough remove a barrel around the marker, and grade the pad. October 11, 1988: The Borough notified the AOGCC that the well sites in question to include wells #12 and #18 were graded to AOGCC specifications and photographs were provided. On October 20, 1988 the AOGCC provided final location clearance for well #12. As for well #18, the Borough concludes the AOGCC may have a more complete record of P&A history and documents produced during the same time period in 1988. The Boroughs purpose is to work with the AOGCC toward removing wells #12 and #18 from the list of 20 permitted wells should historical records demonstrate enough compelling evidence to change well status. The Borough would like to offer our apologies that the letter sent by the AOGCC on July 2, 2019 was not responded to in a timely manner, as we had some staffing changes during that period. The new Division Manager for Fuels and Natural Gas is Allen Snow. I write in Allen's behalf. For future notices, please issue to Allen with a copy to me. — For purposes of this request, please contact me directly at Joe.Ramirez@north-slope.org, if you have any questions regarding review and update of wells #12 and #18. Sincerely, Poe R"dwy Joe Ramirez Division Program Manager Department of Public Works Attachments: Attachment 1 – Plug and Abandonment Well History Cc: Scott Danner, Director Department of Public Works Allen Snow, Division Manager Fuels and Natural Gas Page 2 of 2 qqw NORTH SLOPE BOROUGH DEPARTMENT OF INDUSTRIAL DEVELOPMENT �� ,,,;,„� . ��••� I BARROW GAS FIELD DEVELOPMENT 3201 C Street, Suite 602 Anchorage, Alaska 99503 Phone: 907-561-8820 ;.k P60 S :N' Mr. Lonnie C. Smith: 3 L; October lI, 1988 Commissioner SS' Alaska Oil & GasTEC " A` S'l �•S stn.: tea...,✓_a_ .�p'��=-`-• ///10, ^.'. Conservation Commission+�r�xnaledlnl9 2, Mi:�-� _ 3001 Porcupine Drive Anchorage, Alaska 99501�/;2? F°+� •RcC rc-r9-B$ Re: Photographs of Various Barrow Gas Fields P & A Well Locations Dear Mr. Smith: During our September meeting you indicated that it would be helpful if we provided the AOGCC with photographs of the final site work around the Barrow Gas Fields wells which were plugged and abandoned this spring. Enclosed are four(4) Photographs ( ) photo ra hs of each location (SB #5, #7, #12 and #18) taken immediately following our recently completed grading of the sites. In our opinion these locations now meet AOGCC guidelines concerning restoration of abandoned well locations in actively producing fields, and we respectively request your final approval of this work. Please let either Gary Hammon or myself know if you have any additional questions concerning the condition of the sites, or any other issues related to this matter. Respectfully yours, Erik A. Opstad Geological Consultant North Slope Borough cc: Well Records �1 P MEMO i ALA5I IjIJD GAS CONSERVATIONState G r Alaska OTIIIISSION TO: Lonnie C. Smith i Commissioner Michael T. Hinder THRu: Sr. Petroleum Engineer FROM: Doug Amo3--� Petroleum Inspector DATE: September 2, 1988 FILENO: D.ADA.015 TELEPHONE NO: susJECT. Location Clearance TISB South Barrow No. 12 Barrow Gas Field Sec. 23, T22N, R1717, U.Ti. Tuesday.A��uuggg�st 16 1988: I traveled this date from Anchorage to Barrow to conduct t e ocation clearance inspection on North Slope Borough South Barrow Gas'tlell, tlo. 12. As the attached photograph's and AOGCC Surface Abandonment Report indicate this location has some work to be completed, gravel was removed from the pad and used for road repair. This left the pad area in a very soft and muddy condi- tion and at a much lower elevation then the marker post area. Therefore, I recommend that this location not be granted final clearance status until the pad area is repaired and another inspection is conducted to verity this work. In summary, I conducted th Slope Borough South Barrow work to be done to the pad ante status be granted to performed and verified. Attachment September 22, 1988 e location clearance inspection on North Gas Field No. 12. There is some remaining and I do not recommend that final clear - this location until this work has been Final approval pending. NSB to remove barrel around marker, fill and grade around marker and grade rough area of pad. Pictures showing completed work to be sent to AOGCC.,,'„ r 02-001A (Rev. 8185) N409TH 5L.OPE T3DKCLLC-nH 'Sttx`,t't 8a1� vc.= 6,4 FIit4) iz MRkrze MI4RK t%ZAVL,L "Ma+&D TOIX tadcA PkILKI!W- ?oST �KI•'ACH' A8ANUl',N1:NL' IZP.1'l)i�1 20 AAC 25, ,ONTICLE' 2 FIi,f> INFORMATION: Operator J s Address Surface Location of Well 2 3 Ft, F L L, 1"715'5 Ft, FG L, Sec. v T R J:1, • (�M. _ Date Downhole P & A LA Permit No. -- API No. 50-_ Unit or Lease Name Idol 1 No . Z Field S Pool _ �,;,Q 5.� 20 AAC 25.120: 1;'E1,L ABAND0 ;H'„NT 1-1ARKER: Dia. Steel Post)t " 4Min. ( , Length (10' Min.) Height Above Final Grade Level (4' 1,Iin,) !p r Top of Marker Pipe Closed with: Cement Plug Screw Cap 1�elds L -- Set: On Well Head , On Cutoff Casing / , In Concrete Plug � Distance Below Final Grade Level 2 Ft.� y in. Side Outlets: All Valves and Nipples Removed Y Es All Openings Closed With Blinds With Cement vim, Other INFORIMATIOId BEAD[•:!?I,DED DLIZEC•1'FLY TO HARKEI, POST: (List Where Different from File Information) Operator /�/, Unit or Lease Name Well Number 1 r_- Surface Location of Well: 1 ?,� Ft. F �, L, /�_Ft. , F=C_L, Sec t, R t 1—' 20 AAC 25.170: LOCATION CLEAN-UP PITS: Filled In Liners Removed or Buried Debris Removed SURFACE OF PAD AND/OR LOCATION: Rough Smooth Other /Yl , Contoured Flat Compacted! z l 1,10-,��H ✓� x�J�CI ,�o do l�C }Cs Lc%$9✓�C WIA CLEAN UP OF PAD A;;D/OR LOCATION: Clean , Pipe Scrap Iron Scrap Wood Mud Cement , Paper , Other SURROUNDING AREA: Wooded Brush Tundra `�/; Grass Dirt Gravel , Sand , Other - CONDITION SURROUNDING AREA: Clean Trash from Site Trus and/or Brush from Clearing Site , Other ACCESS ROAD: Dirt , Gravel f, Ice Other CONDITION AC SS ROAD AND SURROUNDING: Clean Rough Smooth _, Trash from Operations Trees and/or Brush from Clearing Road , Spoil from Clearing Road Other ' REMAINING TO BE DONE:h JC1 r j'1 �'Di :f � �' ' /- %0 tl" RECOMM,Et"D• APPROVAL OF ABANDONMENT: Yes No Final Inspection INSPECTED BY �h 1` 'y DATE /(o MA 05/26/81 4 I %r-, s ��t�i' i—i _����f2CiVJ �—'.� � -.F .�,.�,..:,r,=, �. drr 1 ' "[[w�"�. ... s .. n� A� _�4 a .. R.-!:{..�i� r �Rf'�4 � :* ... rx' t f« ,` h�* `�,. �J .� �S� 1 i _el�Ll1Y F.. � �1 IJ ®®ACF, ABi%NUL .`lE'N I' k1`11,010F,c,Aw cs 00 AAC 25, %kTICLE' 2 % )o- 1¢ I I FILE INFO111ATION: Operator M fej"t4. 5[ O zog ,Scj O G - Address g2D% L4, ✓,,�f,� 1a Surface Location of Well. - ! Ft . F : ,� L, -74e- J / �F t . F C L , Sec. Z3 _, T zZ L, RJ'7 Date Downhole P & A 3l/5�8 Permit No. Un,rn�un API No. 50- OZ3 - Unit or Lease Name t1el 1 No. Field & Pool -r- 20 20 AAC 25.120: ltiETA, ABANDONMENT AJIRKER: Dia. Steel Post (4"Min.) +It Length (10' Min.) 21 }{eight Above Final Grade Level (4' Min.) 25 Top of Marker Pipe Closed with: Cement Plug Screw Cap melds 1_ - Set: On Well Head , On Cutoff Casing , In Concrete Plug V� Distance Below Final Grade Level -Z-1 Ft. © '' in. Side Outlets: All Valves and Nipples Removed All Openings Closed , With Blinds With Cement Y'�, Other INFOP'tATION BEADtdELDEID DjREC'IFLY TO MARKET. POST: (List 4,Jlsere Different from File Information) Operator jy S t3O2Ov1(A{i Unit or Lease Name Well Numbery Z Surface Location of Well; ZZ Ft. FAL, Ft. , FEL, Sec, T ZZ _jjR 1'l 20 AAC 25.170: LOCATION CLEAN-UP PITS: Filled In , Liners Removed or Buried Debris Removed _ k( u SURFACE OF PAD Al-7U/OR LOCATION: ���� ' Rough Smooth Contoured Flat Compacted Z Other CLEAN UP OF PAD AND/OR LOCATION': Clean Pipe Scrap t. Iron Scrap ice", Wood Paper Other SURROUNDING AREA: Wooded , Brush Tundra t/, Grass Dirt Sand Other CONDITION SURROUNDI".(: AREA: Mud , Cement , , Gravel Clean Trash from Site Trees and/or Brush from Clearing Site Other LAj ACCESS ROAD: / Dirt , Gravel j/, Ice Other CONDITION ACCESS ROAD AND SURP,OU14DING: Clean , Rough , Smooth ✓ -, Trash from Operations Trees and/or Brush from Clearing Road , Spoil from Clearing Road Other ' REMAINING TO BE DONE: C teLkK " 1 RECOMMEND APPROVAL OF ABANDONMENT: Yes No Final Inspection INSPECTED BY ,,i DATE 05/26/81 STATE OF ALASKA ALAS. IL AND GAS CONSERVATION COMOION APPLICATION FOR SUNDRY APPROVALS am 1. Type of Request: Abandon I!f' Suspend ❑ Operation Shutdown O Reenter suspended well ❑ Alter casing 0 Time extension ❑ Change approved program ❑ Plugging ❑ Stimulate ❑ Pull tubing ❑ Amend order ❑ Perforate ❑ Other ❑ 2. Name of Operator 5. Datum elevation (DF or KB) NorlLmope Borou&h KB = 26' feet 3. Address 3201 "C" Street, Suite 602, Anchorage, Alaska 99503 6. Unit or Property name South Barrow 4. Location of well at surface From Umiat Principal Meridian 7. Well number 22' FSL & 1755' FEL, Sec. 23, T22N, R17W 12 At top of productive interval 8. Permit number As Above Unknown At effective depth 9. API number As Above 50— 023-20006-00 At total depth 10. Pool As Above East Barrow Field 11. Present well condition summary Total depth: measured 2285' feet Plugs (measured) 2088' yAt true vertical 2285' feet �_O,,jk^ Effective depth: measured 2088' feet Junk (measured) None true vertical 2088 ► feet Casing Length Size Cemented Measured depth Tiu Vertical depth Structural R Conductor 20' 24" Unknown 34' 34' Surface 145' 16" 345 sxs. 160' '' ' 160' Intermediate 1062' 10-3/4" 950 sxs. 1076' Productionr+ 618 sxs. 1884 �"a ,.,�,, 1870 7 Liner 201' 5-1/2" None 2062' 2062' Perforation depth: measured 52" Perforated liner 1900' - 2062' (est. by Gruy Management) true vertical As Above Tubing (size, grade and measured depth) 65 its. , 2-7/811, J-55, 6.5#/f t. 8rd @ 2053' BKB , Packers and SSSV (type and measured depth) Not Reported 12 -Attachments Description summary of proposal Detailed operations program Uff'—BOP sketch P8 - 13. Estimated date for commencing operation March 15, 1988 14. If proposal was verbally approved Name of approver Date approved 15. 1 hereby ce and correct to the b st f my knowledge Signed Title Date J© -� Commission Use Only Conditions of approval Notify commission so representative may witness Approval No. Plug Integrity ❑ BOP Test Ur Location clearance (�J �e 00py PA*w endQ _ �U ORIGINAL SIGNED BY -3,11 Approved b LONNIE C. SMITH Y Commissioner 4l A - by order of /W the commission Date .- villi iv."wo rev ICI-ou Submit in triplicate DEPARTMENT OF INDUSTRIAL DEVELOPMENT BARROW GAS FIELD DEVELOPMENT 3201 C Street, Suite 602 Anchorage, Alaska 99503 Phone: 907-561-8820 SOUTH BARROW WELL #12 PROPOSAL SUMMARY AND OPERATIONS PROGRAM March 10, 1988 Proposal Summary Oil "I"orIvruled 1"14 Well #12 was originally drilled by the Navy as an exploratory step -out to test an anticlinal nose similar to the productive structure in the South Barrow Field, The Barrow Gas sands were found to be marginally productive. Most available data on this well has been obtained from a "Drilling and Completion Report, South Barrow Gas Well No. 12, NPR No. 4, Alaska", dated February 28, 1975. Well #12 is currently on production but produces at marginal rates. The surface facilities are old and require steadily increasing maintenance and could pose a safety problem in the near future. Since this well only marginally contributes to village gas deliverability, and may become a safety issue, We feel that abandonment is called for. General Operations Summary To abandon well #12 we intend to employ a quick and simple procedure as follows: 1. R.U. Halliburton, circulate permafrost cement down the 2-7/8" Tbg and up the 2-7/8" x 7" annulus to completely fill the entire hole volume to surface with cement. 2. Close annulus and bullhead 50 sxs. of cement into the formation, R.D. Halliburton & WOC. 3. Observe wellhead pressure, remove wellhead, cut off below ground level and install "Dryhole" marker as per A.O.G.C.C. regulations. We expect operations to commence on or about March 15, 1988 to be completed in less than 24 hours. WELL PD FIELD DISTRICT/ -'STATE GAYS GATE s T T(e�vi Z— Arivw r7i¢S r5e/a CONTRAgOR� �� OPERATION AT REPORT TIME REMARKS RADDnw GAc rrrFn e ON I w WOOF ❑ CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK Weather Temp. Chill Factor Visibility Wind Vel. Signed �f Report OF I OF miles r low 1 t SOUTH BARROW WELL: N2 12 WEl_L..HEAD SCHEMATIC South Barrow # 12 This is the information off of the P&A Marker for WELL # 12: 100— 0 3-5 North Slope Borough�z G�. Barrow Gas Field , South Barrow # 12 23'FSL, 1755' FEL, -O 7 SEC. 23, T22N, R17W, UM ted ? }QG`/rJj 8CeYt G� ✓�v'�GO pw4q, ' L V ALASKAL 011L AND GAS CONSERVATION COMMISSION April 14, 2000 Mr. George Finlayson North Slope Borough P.B. Box 709 Barrow, AK 99723- Subject: 9723 Subject: Plug and Abandonment Well Completion Form 10-407 Permit: 100-026, S. Barrow #4 Permit: 100-030, S. Barrow #7 Permit: 100-035. S. Barrow #12 Permit: 100-046. S. Barrow #18 Dear Mr. Finlayson: TONYKNOWLES, GOVERNOR 3001PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 While doing a computer database check of well status, our well files are incomplete. In checking well status, production reports and the well file, the listed wells completion reports (10-407) and daily well operations, have not been received by the Commission to date. We noticed that correspondence referring to site clearance final approval by the Commission was sent to the operator in 1988 for well S. Barrow #12. These materials are required within thirty days after the abandonment of tie well under our current regulations 20 AAC 25.070(3). This statement has been in our regulations since 1986. Please provide the completion report and daily well operations for the four wells as soon as reasonable, Mav 30, 2000`' Sinc Robert N. Christenson, P.E. Chairman Cc: Each well file o>r r • THE STATE Department of Environmental 011-1LASKL'1 GOVERNOR SEAN PARNELL RECEIVED FEB 0 7 2014 February 4, 2014 A0GCC Certified Mail, Return Receipt Requested Article No.: 7012 2210 0002 1216 2391 Wayne Svejnoha BLM — Division of Resources 222 W 7th Ave, #13 Anchorage, Alaska 99513 Conservation Division of Spill Prevention and Response Contaminated Sites Program File: 320.38.010 SCANNED 0 2 2014 Re: Potentiall Responsible Party Notice Letter and Information Request NPRA Legacy Wells - General Hazard ID: 26125 Ledger Code: 14339387 Dear Mr. Svejnoha: 610 University Ave. Fairbanks, Alaska 99709-3643 Main: 907.451.2181 Fax: 907.451.5105 This letter is to advise you that the Alaska Department of Environmental Conservation (ADEC) has identified the 136 legacy wells within the National Petroleum Reserve in Alaska (NPRA) as potential contaminated sites. Some of these wells require extensive cleanup of oil and other hazardous substances released to the environment. Since you are identified as a current or past owner and/or operator of these sites, please be advised you may be financially responsible or liable for the investigation and /or cleanup of any hazardous substance contamination that might be present. Alaska Statute 46.03.822 establishes who is liable for contamination. Records available to the ADEC indicate that you meet one or more of the following criteria: » owned or controlled the hazardous substance at the time of its release; » own(ed) or operate(d) the property or facility from which the release occurred; » owned or operated property at which the hazardous substance came to be located; and » arranged for transport, disposal or treatment of hazardous substances that were released. Site History From 1944 through 1982 the US Government drilled 136 wells to explore for oil and gas resources in the NPRA. It is our understanding that other federal agencies and some private companies may have operated or managed these sites in the past. We have also been informed that 23 of these well have been conveyed to public and private entities. The ADEC currently lists 14 of the 136 legacy wells on our database of contaminated sites. The Bureau of Land Management (BLM) is identified as the responsible party for the following sites. Wayne Svejnoha 0 2 February 4, 2014 • BLM Cape Halkett Drill Site (File # 300.38.108) • BLM East Simpson #2 (File # 300.38.109) • BLM East Teshekpuk Drill Site (File # 300.38.110) The U.S. Army Corps of Engineers, under the Formerly Used Defense Sites program, is working with ADEC under the Defense States Memorandum of Agreement on cleanup actions at the 11 Umiat test well sites. BLM is identified as the landowner in our records, and as such is identified as a potentially responsible party in addition to the Department of Defense: C Umiat Test Wells 1-11 (File # 335.38.001) The information contained in these files is part of the public record. Our databases are accessible on the Internet at: http://dec.alaska.gov/spar/csp/db_search.httn Additional Actions Needed ADEC sent a letter on July 11, 2013, identifying an additional 15 legacy well sites with confirmed releases (enclosed). As stated in the letter, ADEC recommends that BLM develop a plan to address known, suspected, and unknown releases at the legacy well sites, in coordination with the appropriate regulatory agencies. We expected a response to this letter before now. Please respond to this letter within 30 days. After we receive and review your response we will determine what additional actions will be taken regarding each site with known or suspected contamination. In addition, with your response, please complete and return the enclosed questionnaire requesting more information about past operators. In accordance with Alaska Statute Title 46, ADEC is authorized to provide regulatory oversight for any contamination response efforts initiated by the responsible party. However, if response actions by the responsible party are not satisfactory to ADEC, we may then assume the lead role in the investigation and cleanup efforts. In the event that State response actions are necessary, the responsible parties may be held financially liable for any response actions taken by the State. Alaska Statutes 46.04.010 and 46.08.070 establish cost recovery procedures for certain costs, including oversight activities, incurred by the State in responding to pollution incidents. If you are determined to be a responsible or liable party, ADEC may bill you at a later date for our expenditures associated with this pollution incident. Expenses for which we may seek reimbursement include: Staff time associated with general or technical assistance; work plan review; project oversight; general project management; legal services; interest; travel; equipment and supplies; and any contracting costs. Pursuant to Alaska Statute 46.08.075, the State may also file liens against all property owned by a person who is responsible or liable for State expenditures. Please respond in writing within thirty (30) days from the date of this letter addressing your intended actions with respect to this pollution incident. If you believe someone else is responsible for this pollution incident (e.g., a past owner or operation of the site) or if you have any questions concerning this matter, please contact Mr. Fred Vreeman at (907) 451-2181. The attached "ADEC Information Request" describes the minimum information expected in your response. Additional information may needed to evaluate the risks and responses required at each legacy well site. Sincerely, Fred Vreeman Environmental Program Manager G:\SPAR\CS\Contaminated Site Files (38)\320 National Petro Reserve Area\320.38.010 NPRA Legacy Wells General\2-2-2014 Letter\PRP Letter All Wells.docx Wayne Sveinoha Enclosure: 0 3 • ADEC Information Request Concerning Contaminated Sites BLM Legacy Wells Dispute letter date July 11, 2013 February 4, 2014 cc: Bud Cribley, Director, Bureau of Land Management Steven Cohn, Deputy Director, Bureau of Land Management Jolie Pollet, Branch Chief, Bureau of Land Management Robert Brumbaugh, Geologist, Bureau of Land Management Michael McCrum, Environmental Engineer, Bureau of Land Management Larry Hartig, Commissioner, Alaska Department of Environmental Conservation Lynn Kent, Deputy Commissioner, Alaska Department of Environmental Conservation Kristen Ryan, Director, Alaska Department of Environmental Conservation Lori Aldrich, Program Manager, Alaska Department of Environmental Conservation Steve Bainbridge, Program Manager, Alaska Department of Environmental Conservation Jennifer Roberts, Program Manager, Alaska Department of Environmental Conservation ADEC Response Fund Administration GASPAR\CS\Contarr nmted Site Files (38)\320 National Petro Reserve Area\320.38.010 NPRA Legacy Wells General\2-2-2014 Letter\PRP Letter All Wells.docx 0 0 ADEC INFORMATION REQUEST Concerning a contaminated site(s) Re: Legacy Well Sites in and near the National Petroleum Reserve, Alaska (NPRA) Please precede each answer with the number of the question to which it corresponds. Please direct any questions concerning this information request to Fred Vreeman, Contaminated Sites Program, 610 University Avenue, Fairbanks, AK 99709; Phone: 907-451-2181. Thank you for your cooperation. 1. Provide name and company affiliation of the person answering the questionnaire. 2. Provide copies of all studies, reports, and supporting information (including preaquisition assessments and work done on behalf of other parties) which you have knowledge of which address past and/or present environmental conditions at the site. Identify the name, title, address, and phone number of the party(s) who are responsible for preparing the studies or information. Information which has been previously submitted to ADEC need not be submitted again (unless specifically requested in a subsequent communication) if you can provide the name of the office (and name and title of the DEC officer if known) to whom the report was previously provided. 3. Provide a description of any ongoing or planned investigations or cleanup work at the site. Identify the names, titles and phone numbers of the individuals responsible for preparing the studies or information. 4. Provide a description of known releases at the site (date of occurrence, quantity released, type of substance released, etc.) and a description of corrective measures that were taken. Provide information on any suspected releases which may have or are occurring. 5. Describe the nature of past and present operations at the site. In particular, any actions that may have caused the release or threat of release at the site. Describe the physical characteristics of the site including major structures, water wells, fuel or waste storage systems, drainage or septic systems, etc. 6. Provide a list of any permits issued by the Department which relate to activities at the site and a list of RCRA identification numbers (U.S. EPA identification numbers) which may be held. 7. Identify persons to whom you leased all or a portion of the property and describe the nature of their operations. 8. Identify the person(s) who used the site for disposal of substances deposited there, if any. 9. Provide copies of manifests for any hazardous waste and/or petroleum contaminated materials taken to or from the site. 10. Provide a list of persons and their phone numbers and addresses of persons who have knowledge about the use of hazardous substances at the site. 11. Provide information regarding the existence of insurance coverage for damages resulting from releases of hazardous substances and copies of all such insurance policies, both currently in effect and in effect during the periods of activity in question. 12. Describe the acts or omissions of any person, other than your employees, agents, or those persons with whom you had a contractual relationship, that may have caused the release or threat of release of hazardous substances at the site. a. In addition, describe all precautions that you took against foreseeable acts or omissions of any such third parties. 13. Describe the care you exercised with respect to the hazardous substances found at the site. 14. Describe the physical characteristics of the site including structures, wells, drainage systems, etc. THE STATE July 11, 2013 'ALASKA GOVERNOR SEAN PARNELL Wayne Svejnoha Supervisory Minerals & Energy Specialist 222 W 7th Avenue, #13 Anchorage, Alaska 99513 Re: BLM Legacy Wells Dispute Dear Mr. Svejnoha: Department of Environmental Conservation Division of Spill Prevention and Response Contaminated Sites Program 610 University Ave. Fairbanks, Alaska 99709-3643 Main: 907.451.2181 Fax: 907.451.2155 The Alaska Department of Environmental Conservation (ADEC) — Contaminated Sites has reviewed the National Petroleum Reserve in Alaska: 2013 Legacy Wells Summary Report dated February 2013, containing updated information on the status of the 136 Legacy Wells located in the National Petroleum Reserve — Alaska (NPR -A), and the draft National Petroleum Reserve in Alaslm. 2013 Legacy Weiss Strategic Plan dated May 2013. ADEC has also reviewed the response by the Alaska Oil and Gas Conservation Commission (AOGC). We concur with the response by ACIGC and have no further comment regarding the priorities. We do have comments about the investigation and cleanup plans presented in the report. With this letter we arc outlining regulatory requirements related to the environmental work that is proposed and required as part of these cleanups. ADEC is concerned that the 2013 Legacy Wells Strategic Plan prepared by the BLM does not include either assessment of the contingency for assessment of known, likely, or unknown but possible contaminant releases. In addition, BLM plans for surface cleanup of these wells should be made clear in the plan. At least one of these legacy wells has extensive PCB contamination and has resulted in a multi-year cleanup totaling tens of millions of dollars. At others, solid waste disposal practices have resulted in releases to the environment with estimated cleanup costs in the hundreds of millions. Known releases documented in the records we reviewed include crude oil, gasses, refined oil and fuel, drilling fluids that include various organics, metals, and other chemicals, and unknown contaminants from drums and other containers observed to be damaged and abandoned at the various well sites. There are 13 legacy well sites with known releases currently on the DEC contaminated sites list. Many of these are in the process of being addressed, cleaned up, and closed. From our Waited records review there are 15 additional legacy well sites with confirmed releases. These should be prioritized for initial records reviews and then added to the BLM contaminated sites list under our cooperative agreement. Suspected releases include fuel releases from operations, storage, and fuel spills at the sites, impacts to various surface water bodies from spilled fluids during drilling and breaches of containment at reserve and flare pits, continued surface runoff from drilling fluids uncontained at several sites, and down -hole substances that were ejected from the holes over time or during blowouts or drilling operations. 1 Wayne Sve noha ? July 11, 2013 Y The.BLN-1 plan to address these known, suspected, and unknown releases at legacy well sites is notably absent from the documents presented to date. The three primary regulatory agencies that need to be involved in the plan are ADEC — Contaminated Sites, Alaska Oil & Gas Conservation Commission, and ADEC — EH/Solid Waste. Other agencies will need to be consulted. as well. Below we provide recommendations for a coordinated plan using the Uniform Federal Policy for Quality Assurance Project Plans (UFP-QAPP) that will involve all of the regulatory agencies in one coordinated manner. This will allow BLM to address these sites in a consistent and coordinated project which fulfills all of the regulatory requirements so that the sites do not need to be re -visited in the fu=e xvhen they are closed after this project. Attached are our comments on each specific well. The acronyms used on the list include terms that are typically used in a CERCLA type investigation however they are also suitable for investigations conducted under the State of Alaska cleanup rules. These include the following; Historical Records Review (HRR) 'chis is recommended for almost all of the well sites. Much of the information required for these reviews is already contained in various reports and appendices or in BLM files. The Historical Records Review should document the type of releases that might have occurred from drilling operations as well as historical use of the site, and should capture all available information on the drilling fluids used and any product produced or released. Preliminary Assessment (PA) This is recommended for almost all of the well sites. A Preliminary Assessment is a limited scope investigation that provides an assessment of information about a site and its surrounding area to distinguish between sites that pose little or no threat to human health or the environment and sites that require further investigation. The PA is a CERCLA defined document and typically does not require sampling. Site Inspection (SI) If the PA recommends further investigation, then an SI is necessary. The SI is a CERCLA defined document, and it is analogous to an initial report of contamination under state cleanup rules. On some legacy well drillings sites it is evident now that an Sl is required just from a review of the reports. An SI investigation typically includes the collection of samples to determine what contaminants are present at the site and whether they are being released into the environment. An approved site specific workplan is required under both CERCL-A and 18 AAC 75 prior to SI sampling. The SI typically is not intended to develop a full site characterization, but is limited to determining the presence or absence of a release. If contamination is found after completion of the HRR, PA, and SI then a RI/FS under CERCLA, or a Site Characte-rizatiowlteportandcleanup-Alas,under-l-fi-AAC7iis`required. -- ----- - -- — --------- - DEC recommends that BLM incorporate into the strategic pian the processes outlined in this letter. A team of agencies composed of AOGC, DEC -CS, EPA as required, and DEC -EH should address regulatory and technical requirements for these well closures. By cooperating and working together with the regulatory agencies BLM will save time and expense, and regulatory uncertainties will be avoided. The strategic plan should reference a project to prepare a generic workplan. DEC suggests that BLM utilize the generic UFP-QAPP workplan format for the required environmental work. If properly prepared, the workplan could encompass most of the investigations and cleanups required at these sites over multiple years. At other multi -site projects we have found this to be an effective way to reduce uncertainties and risk in these types of investigations. A very small site specific FSP could then be developed as BLM approaches each drilling site. Regulatory decisions made during workplan development would provide more certainty in the planning process for cleanups. G:\SPAR\CS\federal F2cilitie3\Ci%ih2n 1-cdcrrt Agr=ics\DOl\B[.nl\1'roiens\lxgAey Wells\7 11 13 Luter to KIN on lxbxy wells.doex Wayne Svejnoha 3 0 July 11, 2013 Please review the attached list of specific sites. If you have any questions, please do not hesitate to call me at 907-451-2181 or by email at fred.vreeman@alaska.gov. I look forward to working with you as the Federal Government fulfills its requirement to clean up these well drilling sites in Alaska. Sincerely, y' Fred Vreeman Environmental Program Manager Enclosure: SPAR Response with Legacy Wells cc: Bud Cribley, State Director, Bureau of Land Management Steven Cohn, Deputy State Director for Resources, Bureau of Land Management Jolie Pollet, Branch Chief, Bureau of Land Management Robert Brumbaugh, Geologist, Bureau of Land Management Michael McCrum, Environmental Engineer, Bureau of Land Management Cathy Foerster, Commissioner, Alaska Oil and Gas Conservation Commission Larry Hartig, Commissioner, Alaska Department of Environmental Conservation Kristen Ryan, Director, ADEC Division of Spill Prevention and Response Steve Bainbridge, Program Manager, ADEC Contaminated Sites Program Jennifer Roberts, Program Manager, ADEC Contaminated Sites Program GASI'AR\CS\Fedcrrl Fo61ibLy\Gvi6n Falctul AgcnnCs\DOI\BI.N1\Proitcts\lA'6.1' q W03\7 11 1314tur to Aim\I on Ug2cy Wclls.doex Well Name operator I RP I Land Simpson Core Test #5 1! Na 1 BLM Simpson Core Test #6 US Na I BLM Simpson Core Test #7 us Na 1 Bl. M Sin son Core Test 98 US Navy 113LM Si son Core Test #9 U5 Na I BLM Sinwson Core Test #1f) U.S Navy! BLM Core Test #11 AOGCC Subsurlaca I BLM Core Test #12 FUSNa a I BLM Core Test #16 a 18LM Core Test #17 US Na 1 BLM Core Test 018 US Na I BLM Core Test #19 US Na 1 BLM t Core Test #20 US Navy 1 BLM i Gore Test #21 2S Na 1 BLM I Core Test #22 US Na 111•LM I Core Test dnlf fluids left in hole i BLM Core Test �#2vy I BLhA n CareTest #25 US Na Y I BLM K Core #1 US Navy i BLM 1 -t- *1 SPAR Response with Legacy Wells Lisl.xlsx 2013 Risk Ity CSP Status I Fito tllHazid Rolea5e7 Nnne None IYOMWil Low RNooe ane Nona Unused, Unused. I None Unused, i None Uncased, None None None None (None Unknown Unknown Page 1 of 14 •I AOGCC Subsurlaca AOGCC Surface SPAR W arkgroup Notes Status Status Need HRR, PA, S1 no data no data Need HRR. PA. SI no data no data Need PA ind drill fluid assessnsenl & workplan drillin 11uids left in hole no data Need PA ind drill fluid assessment & work an drilling fluids left in hole no data Need PA incl drill Ifusd assessment & work Ian dnlf fluids left in hole no data Need PA nc drill fluid assessmcnf &work Ian dnllxs fluids left rn hale no data well skc-lch provided by Need PA ind drill fluid BLM not consistent with assessment & work Ian AOGCC or BLM data no data Need PA ind drill fluid assessment & work Ian dnflin fluids left in hole no data Need PA and 51 ind 13611 fluid assessment. workplan rid sampling stressed debfis, partially as blowout and fire rove elated site areas Need PA incl drill fluid assessment & workplan dn lling fluids left in hole no data geed PA ind drill fluid assessment & wOTk Ian drij I ing fluids teff in hole no data Need PA incl dfifl nutd assessment & work Ian drillin fluids left m holo no data Need PA incl drill fluid assessment & work Ian drillin ituids left in hole no data Need HRR. PA, SI no data no data Need PA incl drill fluid assessment & work Ian drillin fluids felt in hole ria data Need PA incl dnll fluid assessment & work larx drillin fluids left in hole no data Need PA incl drill fluid assessment & work Ian drillin fluids Teff in hole no data Need PA ind dnll fluid drflfing fluids and ball assessment & work len peen hammer left in hole no data overshot, drill collar, rock revegelated —131 Need HRR, PA bit, and N -reds left in hole can't find it Review Report as PA. No evidence of sheen, stressed veg, or drilling Not abandoned, waste on surface. Veg ----_— , ,raw,, plunaed to surface site not cleared •I SPAR Response with Legacy Wells LisLxlsx Page 2 of 14 is • vi nce o BLM 2013 Risk Historic AOGCC Subsurface AOGCC Surface Well Name Operator I RP I Land Mgr Priority CSP Status file #IHazid Release? SPAR Workgroup Notes Status Status plugging operations inadequate and Wellhead tell as Umiat 43 US Navy I BLM I FUDS None pending dos 335.38.00113092 Yes. see file 'Plugged by BLM in 2004 incomplete historic site? plugging operations inadequate and Wellhead left as Umiat #4 US Navy I BLM / FUDS None pending dos 335.38.001!3079 Yes, see file Plugged by BLM in 2004 incomplete historic site? plugging operations inadequate and Wellhead left as Umial 98 US NaMy I BLM I FUDS None pendinq dos 335.38.001/3D81 'Yes, see_ _file Plugged BLM in 2004 incomplete historic sile? plugging operations inadequate and Wellhead left as Umiat #1'0 US Navyj BLM_I FUDS None pendingdos 335.38.00113082 Yes, see fila Plu ed by BLM in 2004 incomplete historic site? Need HRR, PA, SI with sampling. Drilling mud assessment. Surface Plugged to 7868'. Drilling Cleanup. Photos - evidence mud and diesel to Awuna #1 USGS I BLM Medium None None Yes of erosion into lake surface. > 100 _Pylons Need HRR, PA, SI with sampling. Drilling mud Wood , metal, assessment. Surface Plugged to 2039'. Diesel plastic debris. Fast Simpson #1 USGS I BLM Low None None Yes Cleanup. to surface. >10D Pylons Need HRR, PA, SI with Wood and metal Drilling mud assessment debris. Pylons - Photos straw areas of no Plugged to 2047'. Diesel Tankage for lk ' #1 USGS / 8LM Low None None Yes ve elation. to surface. flammable fluids Need HRR. PA, SI wdh sampling. Drilling mud assessment. Surface Plugged to 1400'. Drilling Wood and metal Koluktak #1 USGS I BLM Low None None LYes Cleanup. mud & diesel to surface debris Pylons Need HRR, PA, SI with sampling. Drilling mud assessment. Surface Plugged to 1894'. Diesel Wood and metal Ku am 91 USGS I BLM Low None None Unknown Cleanup. to surface debris. Pylons Need HRR, PA, Sl with sampling_ Drilling mud assessment_ Surface Plugged to 4464'. Drilling Wood & metal Kuyanak #1 USGS I BLM Low None None Yes Clean mud & diesel to surface debris. Pylons Need HRR, PA, SI with sampling. Drilling mud assessment. Surface Cleanup. Photos show Plugged to 1840'. Diesel Plastic and metal Lisburne 41 USGS I BLM Low None None Yes stained soil to surface debris. Need HRR, PA, SI with sampling. Drilling mud assessment. Surface Plugged to 8192'. Drilling Wood and metal North Iii ok $1 USGS I BLM Low None INone Yes Cleanup. mud & diesel to surface debris - Page 2 of 14 is • Well Name Peard South Meade #1 1 RP 1 Land 1BLM BLM #1 4USGS ! BLM SPAR Response with Legacy Wells Usl.xlsx ;013 Risk &W CSP Status File XlHazkl T Page 3 of 14 AOGCC Subsurface AOGCC Surface WAR Workgroup Notes Status r Status � deed HERR, PA SI with iampling. Dining mud rssessment- Surface ;leanup. Site photos show areas of stressed iegetalion. No issues Plugged to 2232'. Diesel Wood and metal soled in USGS re ort. to surface debris. Pylons Need HRR, PA, SI with sampling_ Drilling mud assessment Surface Plugged to 2026'. Diesel Wood and metal Cleanup. to surface debris. P Ions Add to She list. Need HRR, PA, SI with sampling. Drilling mud assessment. Surface Cleanup. Od reported bubbling to the surface within reserve pit in 1982. Oily residue and sheen observed adjacent to east side of reserve pil, down hole material at the Plugged to 1875. Diesel Wood and metal surface to surface debris. P ons Add to Site list. Need HRR, PA, S) with sampl'uig. Drilling mud assessment - Surface Cleanup. Reserve pit berm had breaches anowirrg water to exit. Oil - stained sediment was observed above the Plugged to 1478'. Diesel Wood and metal waterline of the I. to surface debris. Site photos may show hydrocarbon sheen on Plugged to 2600'. Drilling Wood and metal water in well cellar mud & diesel to surface debris. Pylons Add to Site list. Need HRR, PA, SI with sampling. Drilling mud assessment. Surface Cleanup. Berms have been breached an allow water to flow out of reserve piUllare pit. Rising bubbles of ail observed in Hare pit 1484. Photos Show Plugged to 1825'. Diesel Metal debris. ra.. v-1 v.nnnralinn to Surface ... 0 •I SPAR Response with Legacy Wells Lisl.xlsx Page 4 of 114 0 0 vi encs o BLM 2013 Risk Historic AOGCC Subsurface AOGCC Surface Well Name Operator 1 RP f Land Mgr Priority CSP Status File #fHazld Release? SPAR Workgroup Motes Status Status Need HRR, PA, Sl wrlh sampling. Drilling mud assessment Surface Cleanup. Breaches in bemi allow water to flow into and out of reserve pit, sheen on Plugged to 2700' Diesel Wood and metal West Dease #1 USGS l BLM Low Nona None Yes surface water in well cellar to surface debns. Pylons Add to Site list. Need HRR,. PA, SI with sampling. Drilling mud assessment. Surface Cleanup. Water flows into the pits through breaches on the eastern berm and out of the pits through breaches on the northern and western berms. Downhole material Plugged to 228'9'. Drilling Wood and metal South Harrison Bay #1 USGS f BLAB Low None None es Present at surface mud & diesel to surface debris. Add to Site list. Need HRR, PA, SI with sampliing. Drilling mud assessment. Surface Cleanup. Stressed vegetation noted and apparent in site pholos. Plugged to 2443'. Drilling West Fish Creek #1 USGS 1 BLM Low None None Yes Drilling mud around well mud & diesel to surface Pylons Need HRR, PA, SI with sampling. Drilling mud assessment, Surface Cleanup. High TPH Plugged to 1977'_ Drilling wellhead sticking concentrations underneath mud under plugs. Diesel up. Wood debris. Fast Simpson #2 USGS 1 BLM I Low _ Active 300.38.10912691 Yes, see file the rig inundation to surface Pylons South Barrow 94 US NavyiNorth Slope Bono None None None Unknown Need Surface Status completed gas well - no data South Barrow #5 USAF - BLM Unknown None None None. Unknown Need Surface Status completed gas well no data South Barrow #& US Na /Norlh Sto Burg None None None Unknown Need HRR, PA, St no data no data South Barrow #9 US NavyfNarih Slop2 Boro None None None Unknown Need HRR, PA, Sl no data no data _ South Barrow #10 US Navyfflorlh Sto Bora None None None Unknown Need Surface Status com ted gas well no data South Barrow It12 US Na /North Slope Baro None None None Unknown Need HRR, PA. Sl no data no data BLM well skMh not consistent with AOGCC South Barrow #14 US NavyMorth Sloe Boro None None one Unknown Nsed HRR. PA, St data no data Need PA ind drill fluid well left filled with drilling South Barrow #16 US NavyiNotih Slope Bora None None None Unknown assessment & workplan mud and diesel no data Need PA incl drill !turd tubing in well. no perfs, Soulh Barrow 017 US Na /North Sloe 13ora None None None jUnknown assessment & work fan I unknown fluid, I no data Page 4 of 114 0 0 SPAR Response with Legacy Wells Lisl.xisx Page 5 of 14 •I E CYfuu .v v AOGCC Subsurface A Surlaco TEHILM T013 Risk CSP Stilus File #IHaaid Historic Rekeasa7 SFAR YUnrkgroup Nates 5latus at US $1<ntus Well Name flperatar f RP f Land Mgriority Unknown Need Surface Status corn feted as well no data 5aulh Barrow #18 US Na INorlh Slo a Bora None None None Unknown Need HRR, PA, St no data no data Walak a #1 USGS! Unknown None None None rsg 890`. Multiple cement plugs of unknown volume. Shallowest None None Unknown _ Need HRR, PA, SI SOD' no dada Gubik #1 US Na d Ur#cnown Low Add to Site list. Need HRR. PA. SI with sampling. csg Q SOD' Well blowout Drilling mud assessment. from zone al 1SOT during Surface Cleanup. Photos plugging operations show disturbed/ slashed Plugging never completed after blowout. no data Gub* #2 US Na ! Unknown Low None Nora es areas two downhole Dement plugs of unknown depth Mone None Unknown Need MR. PA. Sl and volume no data Grandstand #1 US Navy 1 Unknown None Add to Site list. Need HRR. PA, SI with sampling. Dnliing mud assessment. Surface Cleanup Sediment from the reserve pit was excavated and spread over the pad to drill a 2nd well at this location, Upon completion of the 2nd well. the sediment was pushed back into ft reserve pit.. Area does not appear to be revegetaling. perhaps from the presence property plugged but no of drilling mud at the data on abandonment None None Yes surface status no data W 7 Foran #1 " USGS I Unknown Low on Site list. Need HRR, PA, SI with sampling. Drilling mud assessment. Surface Cleanup. Slressed vegetation, photos show plugged, but not open csg; metal & Active 306.3$.108f2689 Yes. see file site underwater abandoned at surface corwsele debris under 5' of water, Cape Halken #1 " US Na (Unknown Low None Unknown !Need HRR, PA. SI es to 27' open C_s Min a Veloei #1 U5 Na f t3LM one None csg @ 31" 280' of drill pipe, drill collar, and Core Unknown Need HRR. PA, SL barrel left rn hole. rove etaled Ournalik Core #i US Na / BLM None -No obsery None !None Page 5 of 14 •I E SPAR Response with Legacy Wells Lisi.xlsx Page 6 of 14 • • WI F3nCe Q BLM 2013 Risk Historic AOGCC Subsurface ADGCC Surface Well Name Operator t RP I Land Mgr Priority CSP Status File #IHazid Release? SPAR Workgroup Notes Status Status Need HRR, PA, Workplan for St with Sampling. Drilling Mud Assessment. Surface Cleanup. Photos show debris, stressed No csg. 15' of drift pipe Oumalik Caro #2 US Navy 1 ULM Low None None yes ve elation and rock hit left in hole. no data Need HRR, PA, Workplan for Si with Sampling open csg & other Drillip) Mud Assessment. piping sticking out Surface Cleanup_ Reports of ground; wood, of debris, drilling muds on melat, conciele Oumalik Core 011 US Navy 1 BLM Low None None Yes surface (__q to 9', debris open csg sticking out of ground; wood & metal 0umalik Core #12 US Navy I BLM Low None None No Need HRR, PA, SI no data —__—debris _„ debris buried by landslide. Need HRR, PA, St, Well not no dala on Sentinel Hill #1 US Navy 1 BLM Low None None Unknown ap panent in site Rholos Csq to 3t1'. underwater status Need IQR, PA, SI. No evidence of sheen, open crag slightly stressed veg, or drilling above ground waste on surface. Veg 37' of csg, drilling fluids level; wood and S imp son Core Test #1 US Navy 1 BLM Low None None No appears healthy lett in hole metal debris Need HRR, PA, St. No evidence of sheen, stressed veg, or drilling waste on surface_ Veg 76'01 Csg, drilling fluids Simpson Core Test #2 US Navy I BLM Low None None No appears healthy left in hate no data Need HRR, PA, Sl. No evidence of sheen, stressed veg, or drilling waste an surface. Veg 61' of csg, drilling fluids Sim sun Core Test #3 US Navy I BLM Low None None No appears healthy left in hole no data Need HRR, PA, St. No evidence of sheen, stressed veg, ordrilling waste on surface. Veg --60' of crag, drilling fluids Sim eson Core Test #4 US Nayy t BLM Low Norse None No apecars healthy left in hole no data Need HRR, PA, St. No evidence of sheen, stressed veg, or drilling waste on surface. Veg csg cemented @25% open csg sticking Songsoncore Test #13 US Na 1 BLM Low None None No appears health dritin fluids IeR in hole_ out of round Need HRR, PA, SI. Vegetated, no evidence of crag cemented @2D'; open csg sticking Simpson Core Test #14 US Navy ! BLM Low None None No release. drillin fluids left in hole out of ground Page 6 of 14 • • SPAR Response with Legacy Wells Lisl.xlsx ism son Core Fest #26 t=vrdence or Medium AOGCC Subsur(aen ADGGC Surface 13LM 2013 Risk CSP Status File WHazid Historic Retease7 SPAR Wwkgroup Notes Status Status Well Name operator r RP 1 Land Mgr Priority Unko Need HRR, PA. SL US Na ! $LM open casing None Nave Vegetated. no ev4dence of cog set shallow; drilling slicking nut of Low No release- fluids left in hole round Simpson Core Teri #14a US Na !BLM Low None None & weilhead slick Need HRR. PA, SI crude nil left in hole open casing Need HIR, PA, Workplan Vegetated, no e+wdence of csg cemented 12181; slicking out of openregd ng No release. drillingfluid left in hole round Simoson Care Tesl #15 US Na !BLM Low None None d wooden Oellar, Need HRR, PP, SL Sate a9 r�110'. dolling fluids wood 8 metal ism son Core Fest #26 US Na ! BLM Medium None None res Sim sen Core Test 027 US Na J 13LM IJone None None Unko Sim son Gore Test #28 US Na ! $LM Low None Nave Yes clmnnnn Core Tesl #29 US Navy! BLM Low Norte No No Simpson Core Test 030 US Na 1 !BLM Core Test #30a JUS,Navy 1 BLM Low `None Prone n Gore Test #31 JUS Navy/ BLM None Page 7o(14 photos appear to show oil at surface, from a natural csg Q 350'. Completed in oil seep, seep, also drilling mud in oil well Open perfs. At 1welhead sticking sacks on the tundra one lime capable of up_ metal debris PI u ed b BLM in 2004. unassisled flow. and rustingbarrels 'Need HRR, PA, St. Site photos appear to show Oil csg cemented at surface, from a natural @i02;dnllutg fluids nn oily ground; csg seep- Plugged by BLM in including diesel and & weilhead slick vin 20014 crude nil left in hole out of ground Need HIR, PA, Workplan for Sl with Sampling- openregd ng ❑rilling Mud Assessment . out grouunnd in Surface Cleanup. Site d wooden Oellar, photos appear to show a p le of drilling mud about a9 r�110'. dolling fluids wood 8 metal 160 feel tram the welt tell in hole debris. Solid waste Need HRR, PA, Sl_ No evidence of sheen, stressed veg, or dri" waste on surface. Veg csg cemented at 1S2'; open csg. Wood a ears healthy dnknq fluids lett in hole and metal debris Need HRR, PA, SI. frilling mud at surface. but well is also in the middle of a large in oil seep; Open oil seep and surrounded by cog sticking up; pooled oil. Plugged by BLNI csg cemented A150'; wood & metal ser Holes in 20514- drillin fluids left in hole detail on oily ground; tog Need HRR. PA, Sl. Well is wellhead slick in the middle of a large oil seep and surrounded by csg cemented at 100% out of ground. pooled oil. Plugged by 131. dulling mud left in hole. wellhead leaking see noses in 2004 gas blowout at 423' gas Need HRR, PA, St. Leaky valve replaced in 2001, little evidence of contamination following valva on city ground; reg replacement- Plugged by csg cemented at 100'; & wellhead stick see notes BLM in 20174 iddifing fluids, left in hole out o1 round SPAR Response with Legacy Wells List.xlsx Page 8 of 14 • • yr enco o BLM 2013 Risk Historic AOGCC Subsurface AOGCC Surface Well Name Operator f RP f Land Mgr Priority CSP Status File glHasid Release? SPAR Workgroup Notes Status Status Need HRR PA, Workplan csg Cemente=d al for Sl with Sampling. 1028', cement plugs a1 Drilling Mud Assessment. 6387' and 5520'. Fish in Surface Cleanup. Drilling hole, drilling fluids Iefs in No data. Open Simpson Test Welt #1 ak US Navy1 BLM Low None INone yes muds near wellhead hale casing Need HRR, PA, Workplan for Sl with Sampling. Dolling Mud Assessment. Surface Cleanup Also Wellhead sticking evidence of a natural seep- above ground, Tar sheens in the summer ST from 2552 to 3018. wood, melel, and months. BLM is concerned csg @2915. Slotted liner concrete debris. Fish Creek #1 US Navy I BLM Medium None None Yes about exposure to wildlife to TO. Completed oil well Rusting barrels Need HRR, PA, Workplan for SI with Sampling. rasing cemented at 48; Drilling Mud Assessment. gas 0mv and explosion Surface Cleanup. Small gas while drilling at 863'; hole leak in wellhead flange, will Filled with fresh water to Wolf Creek 91 US Navy f BLM Low None Nano No flow if the valve iso en 330' No data. csg cemented a[ 53';hole left tilted with fresh water, Wolf Creek 02 US Navy 1 BLM Low Noire Nona No Need HRR. PA. Sl. fish in hole csg cemented at 107'; No data bridge plugs from 1447 to 1735 and from 554 to Wolf Creek #3 US Nayy I BLM Low None None No Meed HRR, PA, SI. 661, No data Add to Site list. Need HRR, PA, SI with sampling. csg slicking out of Drilling mud assessment ground with wood Surface Cleanup. Sheen on plug on top; solid surface water in well cellar, csg cemented at 30'; drill waste; wood hundreds of drums indicate pipe, drilling mud and debris; about 200 Skull Cliff Core iesl #1 US NaMy I BLM High None None Yes polential for cornlamrna[ion diesel left in hole nisling barrels Need HRR, PA, SI. Two open csg, wood drums are floating on a building; pylons; pond near the well. csg cemented at 1000', wood & metal Kaolak 01 US Navy 1 BLM t ow None jNone lNo Potential for hurried landfill. fdriltingluidsieftin hole debris Page 8 of 14 • • SPAR Response with Legacy Wells Lisl.xlsx 181-11119013 Risk Well Name Operator f RP ! land Mgr Priorlty CSP Status File 1NHazid #1 1 U Navy 19LM #1 JUS Navy/ umatik Ill US Na I BLM Low None None as[ Oumalik #i US Na !BLM Low None None #1 N East Topagoruk #1 USN l BLM Kniteblade #1 US Navy l BLM Page 9 of 14 Subsurface `AOGCC Surface SPAR Workgroup Notes Status Add to Site list. Need HRR, PA, SI with sampling. open flange Q Drilling mud assessment. Surface Cleanup. Drilling Gas well. Open ports. ground level. Mud pile overgrown with Drilling fluids and Metal & wood v , etallon and lichen tubulars lett in hole debris Need HRR, PA, SI. No evidence of sheen, stressed veg, or drilling csg cemented at 502'; open casing slicking out of waste on surface. Veg plug at 3470 to 3511'; ground. Wood appears heall drilling nuids left in hole debris. Open casing below Add to Site list. Need HRR, ground level. PA, SI with sampling- Revegetated. Drilling mud assessment. Numerous metal Surface Cleanup. Debris csg partially cemented at I support structures and drilling muds. Stressed 2762'. Plug at 2543% slicking up. vegetation Dridin mud left in hole Concrete debris, plate welded to pipe: l' of pipe rsg cemented at 1100'. sticking up - Need HRR. PA. SI. Drig fluids left in hole Wooden debris. Add to Site list. Need HRR, PA, SI with sampling. Driving mud assessment. open csg broken Surface Cleanup. Downhole material present csg cemented at 6073'. off and sticking up: at surface, area mostly original hole drilled to wood, metal, revegetated. Diesel still 7154'& junk len; concrete and other occupies the ground sidetrack hole left wilh debris. rusting dreulatioir lines. drillina fluids barrel Add to Site list. Need HRR, PA, SI with sampling. Dolling mud assessment. Surface Cleanup. Pile of tsg 10 1100'; pkig al open casing drilling muds is next to the 1049% drilling mud below sticking up. Wood, teller. No offical reserve pit plug: unknown fluids in metal, and glass noted o en hole debris. open casing Need HRR, PA, SI. BLM sticking up. Wood, stales that there was no metal, and glass debris at this site in 2012. csg cemented at 420% debris - •I 0 SPAR Response with Legacy Welts Lisl.xlsx Paye 10 of 14 0 0 w once a BLM 2013 Risk Historic AOGCC Subsurface AOGCC Surface Well Name Operator I RP f Land Mgr Priority CSP Status File #IHazid Release? SPAR Workgroup Notes Status v F Status open casing sticking up. Wood, metal, & concrete debris rusting Need NRR, PA, SI. Reports barrels. One indicate solid waste csg cemented to 45';fish marked flammable Knileblade #2 US Navy I BLM Low None None No drums in hole hazard. open casing slicking up; metal & Krideblade #2a US Navy 1 BLM Low None None No Need HRR, PA, SI. csq cemented at 38% concrete debris Need HRR, PA, SI including learning assessment. Site partially No wellhead. submerged intermittently csg cemented at 80; Metal. Solid waste North Simpson Test Wel 4 US N2n I BLM Low None None No during the summer dri0ing fluids left in hole ? No dala crude wellhead. Need HRR, PA, St. Surface csg cemented at 685'; Wood and metal Umiat 01 US Navy J BLM I FUDS Medium Cleanup co 335.38.00113090 Yes, see file Cleanup drillinq fluids left in bole debris No wellhead. Gravel pad partially csg cemented a1486; revegelaled wood Need HRR, PA, SI. Surface cement plug from 440 to debris and pipe Umiat #i t US Na I BLM I FURS Low pending dos 335.38.00113083 Yes, see file Clea 490'; sticking u csg cemented at 7206'; vVefNwad- Gravel various plugs from 8250' pad revegetaled 7 South Sirnpson 01 US Navy I BLM Low None None Yes Need HRR, PA, SI. to surface No data Add to Site list. Need HRR, PA, SI with sampling. Drilling mud assessment. Surface Cleanup. Large quantifies of ferrous oxide, zinc oxide, zinc carbonate, and barium sulfate were added to drilling muds. Stains apparent in photos. BLM field camp an site. Walls between the reserve and Pare pits have eroded. Wellhead and Water flows into surface gravel pad. ? No Wook #1 USGS I BLM Low lNone Name Yes water during break22L no data data Paye 10 of 14 0 0 SPAR Response with Legacy Wells Lrsl.xlsx BLM 2x13 Risk Well Name 10porator I RP I Land Mgr Priority CSP Status I File #IHazid Arca- Barrow Cure #1 US Na l til.M Avak 01 US Navy I BLM Barrow Bi R' #1 US Na I BLM Barrow Cafe Rig Test 91 US Na I BLM #2 I US Navy I BLM #1JUS N,a I BLM H' h NOr1e None Test Well #1 US Test Well #2 US Barrow Test Wetl #31115 Na IN©r1h Slo c Bora IAedium None None Unknown Page 11 of 14 Subsurface -FAOGCC Surface SPAR IWorkgfoup Notes Status _ ___ araiu5 Need HRR, PA, SI. Surface Cleanup, Photo CIMG0218 csg cemented at 53` shows area of disturbed tubing hung to 708': hole open casing vegetation that should be heft filled with drilling mud slicking up; wood & investi algid durin Sf and diesel metal debris open casing Need HRR. PA, St. Surface csg cemeoled at BIF. sticking up; wood & Cleanu-. lu set at 1348' metal debris Not abandoned, site not cleared, Need HRR, PA, SI. Surface open easing 7? No Cleanup no data data Not abandoned, site not eteared, Need HRR. PA, SI. 'Surface open casing 77 No Cteanu no data data Need HRR, PA, St with sampling. trilling mud assessment. Surface Cleanup. Drilling Muds on Not abandoned, site -slowly revegelatmg site not igred, More information on drilling open casing 7? No mud specifics rs being researched no data data Need 1lRR, PA, SI wdh sampling. Drilling mud wellhead leaking assessment. Surface cemented Csg to gas!? Wood & Cleanup- Cellar does not 1270;slotted liner to metal debris. Area retain water 1956': tbg to 1939 affected 50'x50' Need HRR, PA. SI. Drilling Csg cemented at mud assessment. Surface 441'.hole Iell willed with open pipe; metal & Cleanup- On mads stem water concmie debris Need HRR, PA, Sl. Drilling Csg cemented al 2260'; mud assessment- Surface periorated liner to TD. wood, metal & Cleariu . fln road s stem lin Completed well. Conerete debris Need HRR, PA, SI with sampling and workplan. Drilling mud assessment. Surface Cleanup. Drilling +csg cemented at 10461: open c5g slinking mud at surface. Sheen on hole left filled with drilling up; wood & metal surface wafer in well cell larQuids and wafer. de" 0 SPAR Response with Legacy Wells Lisl.xlsx Well Flame Operator I RP I Land Mgr BLM 201$ Risk Priority CSP Status File #ltiazid yr once oF— Historic Release? SPAR Workgroup Notes AOGCC Subsurface Salus g AOGCC Surface Status no data. Likely revegetaled. Removed from our list of wells of concern in < 50', no csg, no API#, October, 2012 Oumalik Foundation Tess A US Navy I BLM None-uncased hc None None lUnknown Need HRR, PA. not in AOGCC database Monlht Meeting no data. Likely revegetated. Removed from our fist of wells of concern in < 50', no csg, no API#, October, 2012 Cumalik Foundalion Test b US Navy I BLM None-uncased hC None jNane Unknown Need HRR. PA, not in AOGCC database Monthly Meeting no data. Likely revegetated. Removed From our irsl of wells of Concern In < 50', no csg. no API#, October, 2012 Oumalik Foundation Test A US Navy I BLM None-uncased hc None lNone Unknown Need HRR. PA, not m AOGCC database Monthly Meeting no data. Likely revegetated. Removed from our list of wells of concern in < 50', no c5g. no APF#. Odubut. 2012 Oumalik Foundation Test A US Navy I BLM None-uncased ht Nune lNone Unknown Need HRR, PA, nal in AOGCC database Monthiv Meetin no data. Likely revegetaled. Removed from our Ilst of wells of con cam in < 501, no csg, no APi#. October, 2012 Oumatik Foundation Test 0 US NavyI BLM None-uncased hc None None Unknown Need HRR. PA, not in AOGCC database Moral Meeting no data. Likely revegetaled. Removed from our list of wells of concern in < 50', no csg. no API#, October, 2012 Ournalik Foundation Test 4US Navy I BLM None4xwased h_j None None Unknown I Need HRR. PA, not in AOGCC database Month Meetin Page 12 of 14 0 Page 13 of 14 SPAR Response with Legacy Wells LrsLxisx Well Name BLM 2013 Risk Operator f RP I Land Mgr Priority Historic CSP Status Fife #IHazld Rslease7 AOGCC subsurface Status �__ - -_-�� . A013CC Surface Status no dala. Likely SPAR 1Norkgroup Nates revegelaled. Removed from our list of wells of concern in < 50'. no csg, no AP IN, October, 2012 Oumalik Foundation Test US Na!q BLM None -encased h None None Unknown Need HRR. PA. not w AOGCC database MonthlyMeetin no data. Likely revegelated. Removed from our list of wells of concern in < 501. no csg, no API#, October, 2012 Oumalik Foundalion rest U5 Na I BLM None -encased h None None Unknown Need HRR, PA, not in AOGCC database Monihl lAeeli no data. Likely revegetaled. Removed from aur fist of wells of concern in 0urn alik Foundation Test US Na 18 LM None -encased fi None None ilnknown Need HRR. PA, < 50', no csg. no API#, not in AOGCC database October, 2012 Month! Meetin no data. Likely revegetated. Removed from our list of wells of concern In < 50', no csg, no API#, October, 2012 Oumalik Foundat'Gon Test US Na I BLM None encased h Nome None Unknown Need HRR, PA, not m AOGCC database Month! Meeting property abandoned per then -applicable South Banow #7 US NEILM 2LI None None Unknown Need HRR. PA, ro erl lu ed re s no data to support proper Um -Qt 02 US N Noire Pendin Clo 335.30.001/3078 Yes, see file Plu d to surface abandonment no data to support proper Uncal #5 Ummt #9 Urrval A66 Umial #T Atiaaru Point#1 U5 US US Na I BL M US Na I BLM USGS/BLM None Pendin Hi h -PCB cleanu Active None Pendia None tPendi Mane Clo 3L5 313.00113079 335.38.00113093 Cao 335.3$.00113080 Clo 335 38 001I3091 None Yes, see file Yes, see file Yes, see file Yes. see lite No Plu ed E4 surface property plugged and abandoned pfupedy plugged and abandoned property plugged and abandoned Need HRR. PA,Plugged by properly plugged and BLM in 2009. abandoned abandonment suriaoe site rcmediated surface site remediated suriacx V le remediated surface site re medialed Page 13 of 14 SPAR Response with Legacy Wells LrsLxlsx Page 14 of 14 0 vrcTon`ce o BLM 2813 Risk Historic AOGCC Subsurface AOGCC Surface Well Name Operator i RP 1 Land Mgr Priority CSP Status File #fFlaxid Releases SPAR Workgroup Notes Status Status Add to Site list. Need HRR, PA. SI with workplan and sampling. Chilling mud assessment. Surface Cleanup. Two large breaches on the south side of the berm allow water out of the reserve pit. Plugged properly plugged and surface site Drew Point #1 USGS 1 BLM None None None Yes by BLM in 2410. abandoned remedialed On Site list Need HRR, PA, 51 with workplan and sampling. [frilling mud assessment. Surface Cleanup. In 1976 the reserve pit berm failed and dolling muds/cutlings were released onlo the Poe of Teshekpuk Lake. Plugged by BLM in 2008. Solid waste from camp aril drilling operations buried on northern portion of pad. Erosion has exposed solid properly plugged and surface site East Teshek uk #1 US Navy 1 BLM None Active - waits 3Q0.38.11012652 Ycs, see file waste. abandoned remediated Threatened by erosion. properly plugged and surface site J. W. Dalton $P USGS f BLM None None None No Plu ed b BLM in 20fl5. abandoned rernediated properly plugged and surface site South Barrow #8 USAF 1 BLM None None None Unknown Need HRR, PA, abandoned remediated properly plugged and surface sile South Bartow 911 US Na INorih Slope Bono None None None Unknown Need HRR, PA, abandoned remedialed properly plugged and surface site South Barrow 013 US Na lNerlh Slope Boro None None None Unknown Need HHR, PA, abandoned remedialed properly plugged and surface site South Barrow #15 US Na !North Sloe Boro None None None Unknown Need HRR, PA, abandoned remediated properly plugged and surface site South Barrow #19 US Na 1Nrarlh Sloe Baro None Nana None Unknown Need HRR. PA, abandoned remediated Properly plugged and surface site South Barrow 1x20 US Na Worth Slope Bora None None None Unknown Need HRR, PA, abandoned remedialed Need HRR, PA, dolling mud assessment, containment assessment, possible releases. Breaches allow wafer to flow into and aul of property plugged and surface site Watakpa #2 USGSI BLM None None lNone lyes I reserve and flare pits. labandoned irernediated Page 14 of 14 0 c,o — 6.35 //7%0 THE STATE ! mart i_it LtilIVLL'enmertai. oJ �1'l ��a.� E�. .. C�'1�se1;`Wc3.�LF'i��i ?d�c. 14_ __ Division of Spill Prevention and Response _= Contaminated Sites Program GOVERNOR SEAN PARNELL �' rn gip.'p 610 University Ave. ALAS-- Fairbanks, Alaska 99709-3643 Main:907.451.2181 Fax:907.451.2155 July 11, 2013 Wayne Svejnoha SCANNED MAR I I. 2314 Supervisory Minerals & Energy Specialist 222 W 7th Avenue, #13 Anchorage,Alaska 99513 Re: BLM Legacy Wells Dispute Dear Mr. Svejnoha: The Alaska Department of Environmental Conservation (ADEC) —Contaminated Sites has reviewed the National Petroleum Reserve in Alaska: 2013 Legacy Wells Summary Report dated February 2013, containing updated information on the status of the 136 Legacy Wells located in the National Petroleum Reserve— Alaska (NPR-A), and the draft National Petroleum Reserve in Alaska: 2013 Legacy Wells Strategic Plan dated May 2013. ADEC has also reviewed the response by the Alaska Oil and Gas Conservation Commission (AOGC). We concur with the response by AOGC and have no further comment regarding the priorities. We do have comments about the investigation and cleanup plans presented in the report. With this letter we are outlining regulatory requirements related to the environmental work that is proposed and required as part of these cleanups. ADEC is concerned that the 2013 Legacy Wells Strategic Plan prepared by the BLM does not include either assessment or the contingency for assessment of known,likely, or unknown but possible contaminant releases. In addition,BLM plans for surface cleanup of these wells should be made clear in the plan. At least one of these legacy wells has extensive PCB contamination and has resulted in a multi-year cleanup totaling tens of millions of dollars. At others, solid waste disposal practices have resulted in releases to the environment with estimated cleanup costs in the hundreds of millions. Known releases documented in the records we reviewed include crude oil,gasses,refined oil and fuel, drilling fluids that include various organics,metals,and other chemicals,and unknown contaminants from drums and other containers observed to be damaged and abandoned at the various well sites. There are 13 legacy well sites with known releases currently on the DEC contaminated sites list. Many of these are in the process of being addressed, cleaned up, and closed. From our limited records review there are 15 additional legacy well sites with confirmed releases. These should be prioritized for initial records reviews and then added to the BLM contaminated sites list under our cooperative agreement. Suspected releases include fuel releases from operations, storage, and fuel spills at the sites,impacts to various surface water bodies from spilled fluids during drilling and breaches of containment at reserve and flare pits, continued surface runoff from drilling fluids uncontained at several sites, and down-hole substances that were ejected from the holes over time or during blowouts or drilling operations. , Wayne Svejnoha 2 July 11, 2013 The BLM plan to address these known, suspected, and unknown releases at legacy well sites is notably absent from the documents presented to date. The three primary regulatory agencies that need to be involved in the plan are ADEC —Contaminated Sites,Alaska Oil& Gas Conservation Commission, and ADEC—EH/Solid Waste. Other agencies will need to be consulted as well. Below we provide recommendations for a coordinated plan using the Uniform Federal Policy for Quality Assurance Project Plans (UFP-QAPP) that will involve all of the regulatory agencies in one coordinated manner. This will allow BLM to address these sites in a consistent and coordinated project which fulfills all of the regulatory requirements so that the sites do not need to be re-visited in the future when they are closed after this project. Attached are our comments on each specific well. The acronyms used on the list include terms that are typically used in a CERCLA type investigation however they are also suitable for investigations conducted under the State of Alaska cleanup rules. These include the following; Historical Records Review (HRR) This is recommended for almost all of the well sites. Much of the information required for these reviews is already contained in various reports and appendices or in BLM files. The Historical Records Review should document the type of releases that might have occurred from drilling operations as well as historical use of the site, and should capture all available information on the drilling fluids used and any product produced or released. Preliminary Assessment (PA) This is recommended for almost all of the well sites. A Preliminary Assessment is a limited scope investigation that provides an assessment of information about a site and its surrounding area to distinguish between sites that pose little or no threat to human health or the environment and sites that require further investigation. The PA is a CERCLA defined document and typically does not require sampling. Site Inspection (SI) If the PA recommends further investigation, then an SI is necessary. The SI is a CERCLA defined document, and it is analogous to an initial report of contamination under state cleanup rules. On some legacy well drillings sites it is evident now that an SI is required just from a review of the reports. An SI investigation typically includes the collection of samples to determine what contaminants are present at the site and whether they are being released into the environment. An approved site specific workplan is required under both CERCLA and 18 AAC 75 prior to SI sampling. The SI typically is not intended to develop a full site characterization, but is limited to determining the presence or absence of a release. If contamination is found after completion of the HRR,PA, and SI then a RI/FS under CERCLA, or a Site Characterization Report and cleanup plan under 18 AAC 75 is required. DEC recommends that BLM incorporate into the strategic plan the processes outlined in this letter. A team of agencies composed of AOGC, DEC-CS, EPA as required, and DEC-EH should address regulatory and technical requirements for these well closures. By cooperating and working together with the regulatory agencies BLM will save time and expense,and regulatory uncertainties will be avoided. The strategic plan should reference a project to prepare a generic workplan. DEC suggests that BLM utilize the generic UFP-QAPP workplan format for the required environmental work. If properly prepared,the workplan could encompass most of the investigations and cleanups required at these sites over multiple years. At other multi-site projects we have found this to be an effective way to reduce uncertainties and risk in these types of investigations. A very small site specific FSP could then be developed as BLM approaches each drilling site. Regulatory decisions made during workplan development would provide more certainty in the planning process for cleanups. CZ.\CDA12\ \r;.,;1:,.,FPri..,lAoPnriPS\Tl(1T\RT.M\Proiects\Le¢acv Wells\71113 Letter to BLM on Legacy Wells.docx Wayne Svejnoha 3 July 11, 2013 Please review the attached list of specific sites. If you have any questions, please do not hesitate to call me at 907-451-2181 or by email at fred.vreernan @alaska.gov. I look forward to working with you as the Federal Government fulfills its requirement to clean up these well drilling sites in Alaska. Sincerely, Fred Vreeman Environmental Program Manager Enclosure: SPAR Response with Legacy Wells cc: Bud Cribley, State Director, Bureau of Land Management Steven Cohn, Deputy State Director for Resources, Bureau of Land Management Jolie Pollet, Branch Chief, Bureau of Land Management Robert Brumbaugh, Geologist, Bureau of Land Management Michael McCrum, Environmental Engineer,Bureau of Land Management Cathy Foerster, Commissioner, Alaska Oil and Gas Conservation Commission Larry Hartig, Commissioner,Alaska Department of Environmental Conservation Kristen Ryan, Director,ADEC Division of Spill Prevention and Response Steve Bainbridge, Program Manager,ADEC Contaminated Sites Program Jennifer Roberts, Program Manager,ADEC Contaminated Sites Program G:\SPAR\CS\Federal Facilities\Civilian Federal Agencies\DOI\BLM\Projects\Legacy Wells\7 11 13 Letter to BLM on Legacy Wells.docx .„---°* - - - O 2 u CO T,� CO -0 t O CO $ 0 N = C N co N N = co C U U N N c0 co co Co co CO co a 00 N CO CO a) 07 CO CO CO 5 co U 7 CO N Co Co co co co Co .N a) c0 Co CO cO N Co c0 TO CO 0)w N C 1 O .y C.. 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C C cu U Z Q Z Z Z Z Z_ Z Z Z Y N C0 M r N . 2 .0 o C a) C C a) C C C C CO 0 0_ z z0 0 0 0 0 Z 0 Z 0) o 0 0 0 0 coo m m m m co CD d a) N a) O. n C. n a 1° 0 0 0 0 0 J 3 2 t t t t t CO 2 2 0 O O O O 2 -J J J z z z z z J w m m CO CO CO CI)L. 0 Q 2 CO CO CO Z 0 O j cn rn Cr) CO (.0 m u) U) Cl) 4t '— M in 0) 0 _ Y 1- Co 4k 4k 4k 46 # d 4* Y C 0 0 0 O 0 O C d ` L. N IL qt Z a N 0 CO c0 CO c0 m m 0. d 12 N 0 0 0 0 0 To o co --i co in co 0) co in Cl)° .~ .- ~... '., r .. .. " ··'e :........-./ e "-- (6~{ d f1 \ ~f ð'D MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Co~iS$ion \ TO: Dan Seamount, i!'S' DATE: Commìssione~ ::..( ¿; ~ Blair Wondzell, ~ SUBJECT: P. I. Supervisor t1{fl.{/Ðð John H spaUldi~~ J ò(~"1 5 Petroleum Inspeçtor August 31, 2000 THRU: Barrow Gas Field South Barrow Field , ' " ,~..t I f)tY.J' ,;¡' FROM: AUJ:1ust 31,2000; I traveled to the Barrow Gas Field to review their records for "proper': Plug and Abandonment procedures on the following wells. SouthnBarrow Test.well #4 pro 100-026 : ~, There is no data on any type of P&A. From our records it appears that the well was drilled in 1950 by the U.S. Navy, production was apparently curtailed in 1968. The well still has a coverlwellhouse over it, there is $till wellhead attached. As the accompanying pictures denote the area around the well head is covered in water. I was unable to find anyplace that would show there was a reselVe pit, it is quite possible that the reselVe pit was removed. I suggest that before writing this well off as P&A'd, that the US Navy be contacted in an effort to find out where cement in the well bore might be. I recommend that this well have the well house removed, the well head removed, the casing blinded off and at a minimum a mound of gravel or dirt placed around the well to keep the water from impacting the casing as well as mitigating a safety hazard. South Bar(ow # 7 NSB-07DP, PTD 187-075: , - According to Halliburton's job log and billing statement this well was P&A'd 3-29- 88, the AOGCC records show the well was removed from production status .and P&A'd on 11/17/88. The well has a dry hole marker that appears to be placed in the cement after the well head was removed - no welded cover. From the pump reports it appears that cement was circulated down the production tubing with returns being taken thru the annulus. Once cement was observed at surface the annulus valve was shut in, squeeze pressure was obtained and a volume was placed behind pipe or into the formation. Considering the depth of these wells (shallow) this is probably a good cement job, therefore a prettv good PM. , . /"\ l I recommend that the well be dug out 3' below original grade, dasings cut off and a welded cover be placed on the casing stub. As these wells are close to town this would mitigate a safety concern of mine with the winter snow machine traffic. ZOO® XVd CO:Zl gOOZ/g!/60 e e '---, .~. .~ South Barrow # 12. PTD 100-0_35 and South Barrow # 18, PTO 1 00-04~: These wells were P&A'dat about the same time as well number 7, same contractor and the same procedure was used. Contractor billings were used to obtain this information as well. No. Sundries were applied for or issued for these 3 wells. . As noted in the pictures the casing on well # 12 is tore up some, and it appears that the dry hole marker has been placed in the cement at the top of the casing. There is no evidence of a reserve pit in the area. Well 18 as shown in the pictures, has the same type of surface abandonment, with the exception of the reselVe pit area. The reserve pit area has been broached and some of the gravel has been removed.· . I recommend that these three wells be cut off 311 below original grade the casing stubs blinded with a welded cap and a mound of gravel placed over the casing. Fa~ilities While in Barrow I visited the facilities that are currently in use. These will be replaced in the near future. The new facilities are on 10c~Jion but have not been commissioJled as yet . . .~ I was particularly interested in the current and future LACT metering systems. When at peak usage this meter handles about 6mmcf daily, a relatively small amount. I am not familiar with the current Rockwell "Electro Corrector" system that is in use, this is a charted turbine meter. This meter is "checked" on a monthly basis and is compared to the Barrow Utilities Sales meter. This meter is calibrated on an annual basis. In the new facilities there are 3 separate runs, one for each field with a "Daniels" computerized orifice plate meter. These will feed into a 4"\ine that contains the "Daniels" LACT meter. The new facilities are quite a step up from where they are today. SUMMARY (by BlairWondzell): . . 1. - Soüth Barrow wells 7,12, and 18 appear to be properly plugged but should be cut off at least 3' below original ground level and a marker plate installed. 2. South Barrow well #4 does not appear to be properly plugged; the well house should be removed, downhole plugs installed and casings cut off at least 3' below original ground level and marker plate installed. 3. The AOGCC should make an annual inspection that would coincide with the calibration of the gas meters. Attachment: Pictures ~ ·Q~~';:savåk~· \:'·Ú,;:~~i;;~,,;:,:,..;...,,·~::'" '.' ..' , COO® XVd CO:ZI gOOZ/g!/60 JPE('.,image 320x240 pixels e .e ,---. -~ .~ Subject: pictures Date: Tue, 05 Sep 200015:17:05 -0800 From.: John Spaulding <john_spaulding@admin.state.ak.us> ùltemal Organization: AOGCC To: BlairE Wondzell <blair_wondzell@admin.state.ak.us> Blair, how are these coming. thru. js ~: - ~ ~ lof3 f700~ Roc.lwe 1\ It ~( 1- \. 1::'"1 e.~."W·O Cor~+Ö(" S ß $ (8 9114100 12:07 PM XVd CO:Z1 900Z191/60 , . re~G i,o..~gß;320x240 pixelS e ,. ...........~ ~ \ ~ ~ 2of3 £OOiÈj -e sa ~7 S 13 JS: IS ;G ß .: 1 '2.. 9/14/00 12:07 PM XVd CO:ZT £OOZI£T/60 · . J!'EG~~~ 320¡QA0 pìxc:la e ,e '~. --.-- ~ 5ß..r,t:1{ Name: Untìtled~i.pdd ~ UI1titled-l.pdd Type: application/x-unknown.content-type-pdd.:...auto _file Encoding: þase64 .. 11-0-.0' " ~ , ~ 300 9/14/0012:07 PM 900® XVd VO:Z1 9007,/91/60 . . ~ ,..... f'" e e NORTH SLOPE BOROUGH DEPARTMENT OF PUBLIC WORKS UTILITIES-FUEL P.O. BOX 69 BARROW, ALASKA 99723 TEPHONE NO. 907-852-0390 FAX NO. (907) 852-0327 FAX TRANSMITTAL Organization STEVE ~c /v\",:¡.zN....s Ii q 6- c;.Ç.. TO; Name Fax No. .1-. 76 ~ 75-42 FROM: .S7E Pc ... /Y\.ðc.. IZ.w9$ DATE: c:¡ .. IS' 05' Total number of pages, including this page 6 MESSAGE: _ STE¡/£ ~ I1T11i¢flED .Is í}/t= TÞ D,qx. SFAAACVNí L.£r""~p DATE/) FJ2ðA/lo. ::J.ðh'».... SP,An,þ7')'/¿'" . ¡;lLJ6-L/.o$7" .3 J / 2.,¢bC . 'fLll}§£, J Gr. /V\.Jt /(NCJ\N. 7f YfJ/1 AlGI£.}) J'JtJYTH$N/;'. £¿S¡t:" . ~ ···2 ~J?~_ ~ PLEASE CALL US IF YOU DON'T RECEIVE ALL PAGES. ". r··..- f·.· f ,- ~ " ~,. ."". '.'. ".'~ ~.~ ~-" .i 'oj ~- ~ ) ~ ,,~:;... ~ ("'- :l~;,,:.;.. <.-.....,>' , ,.)k 100~ -\>"~ O:~\ & G¡ro i).ANi. C^.:·¡lrá~~~'f J'I~\~\·.~''J.:)~ XVd CO:Zl £OOZI£1/60 (C2i ( j/j\"l! ì ç I n¡. i! CU! VI ! \ . .- - ~- .,,- TONY KNOWLES, GOVERNOR AI,ASIiA. OILA5D GAS CONSERVATION COMMISSION 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 April 14, 2000 Mr. George Finlayson North Slope Borough P.B. Box 709 Barrow, AK 99723 Subject: Plug and Abandonment Well Completion Form 10-407 Permit: 100-026, S. Barrow #4 Permit: 100-030, S. Barrow #7 Permit: 100-035. S. Barrow #12 Permit: 100-046. S. Barrow #18 Dear Mr. Finlayson: While doing a computer database check of well status, our well files are incomplete. In checking well status. production reports and the well file, the listed wells completion reports (10-407) and daily well operations, have not been received by the Commission to date. We noticed that correspondence referring to site clearance final approval by the Commission was sent to the operator in 1988 for well S. Barrow #12. These materials are required within thirty days after the abandonment of t't.e well under our current regulations 20 AAC 25.070(3). This statement has been in our regulations since 1986. Please provide the completion report and daily well operations for the four wells as soon as reasonable, May 30, 2000? ;gn Robert N. Christenson. P.E. Chairman Cc: Each well file ( ALASKA INDIVIDUAL WELL PRODUCTION AS OF 04/05/2000 WELL-NAME: S BARROW 12 API: 023-20006-00 LEASE: FEE-NSB OPERATOR: NORTH SLOPE BOROUGH FIELD/POOL: EAST BARROW, EAST BARROW SALES CD - 15 ACCT GRP - 001 FINAL STATUS: DEV 1-GAS CURRENT STATUS: ** GAS PRODUCTION ** 1981 JAN FEB MAR APR MAY JUN JUL AUG SEP OCT NOV DEC METH FLOWING DAYS 1 OIL WTR GAS 5 1981 TOTALS OIL WATER GAS 5 CUM OIL CUM WATER CUM GAS 5 1982 JAN FEB MAR APR MAY JUN JUL AUG SEP OCT NOV DEC , METH FLOWING FLOWING FLOWING FLOWING FLOWING FLOWING FLOWING SHUT-IN FLOWING FLOWING FLOWING FLOWING DAYS 1 28 31 30 31 30 25 1 31 30 30 OIL WTR GAS 12 3,042 3,356 3,247 3,367 3,244 2,685 21 3,253 3,143 2,952 1982 TOTALS OIL WATER GAS 28,322 CUM OIL CUM WATER CUM GAS 28,327 1983 JAN FEB MAR APR MAY JUN JUL AUG SEP OCT NOV DEC METH FLOWING FLOWING FLOWING FLOWING FLOWING FLOWING FLOWING FLOWING FLOWING FLOWING FLOWING FLOWING DAYS 31 28 31 15 31 1 23 4 30 21 12 31 OIL WTR 20 6 7 GAS 2,351 3,366 1,298 638 229 22 1,450 599 1,581 2,033 1,236 849 1983 TOTALS OIL WATER 33 GAS 15,652 CUM OIL CUM WATER 33 CUM GAS 43,979 1984 JAN FEB MAR APR MAY JUN JUL AUG SEP OCT NOV DEC METH FLOWING FLOWING FLOWING FLOWING FLOWING FLOWING FLOWING FLOWING FLOWING FLOWING FLOWING SHUT-IN DAYS 25 10 12 30 31 30 25 31 26 1 2 OIL WTR GAS 2,496 675 244 402 406 384 414 418 477 14 498 1984 TOTALS OIL WATER GAS 6,428 CUM OIL CUM WATER 33 CUM GAS 50,407 , 1985 JAN FEB MAR APR MAY JUN JUL AUG SEP OCT NOV DEC METH SHUT-IN FLOWING SHUT-IN FLOWING FLOWING FLOWING FLOWING FLOWING FLOWING FLOWING SHUT-IN SHUT-IN DAYS 6 9 16 4 31 31 30 31 OIL WTR GAS 125 630 252 92 793 312 266 36,158 1985 TOTALS OIL WATER GAS 38,628 CUM OIL CUM WATER 33 CUM GAS 89,035 1986 JAN FEB MAR APR MAY JUN JUL AUG SEP OCT NOV DEC METH SHUT-IN SHUT-IN SHUT-IN SHUT-IN SHUT-IN SHUT-IN FLOWING FLOWING SHUT-IN FLOWING SHUT-IN SHUT-IN DAYS 1 1 31 OIL WTR 1 16 13 GAS 4 10 2 1986 TOTALS OIL WATER 30 GAS 16 CUM OIL CUM WATER 63 CUM GAS 89,051 ALASKA INDIVIDUAL WELL PRODUCTION AS OF 04/05/2000 1987 JAN FEB MAR APR MAY JUN JUL AUG SEP OCT NOV DEC METH SHUT-IN SHUT-IN SHUT-IN SHUT-IN SHUT-IN SHUT-IN SHUT-IN SHUT - IN SHUT-IN FLOWING SHUT-IN SHUT-IN DAYS 1 OIL WTR GAS 8 1987 TOTALS OIL WATER GAS 8 CUM OIL CUM WATER 63 CUM GAS 89,059 1988 JAN FEB MAR APR MAY JUN JUL AUG SEP OCT NOV DEC METH SHUT-IN SHUT-IN SHUT-IN SHUT-IN DAYS OIL WTR GAS , 1988 TOTALS OIL WATER GAS CUM OIL CUM WATER 63 CUM GAS 89,059 , ALASKA OIL AND GAS CONSERVATION COMMISSION PETROLEUM WELL RECORD - Commission use only - 04/05/2000 +----------------------------------------------------------------------+ -~~~~~--I---~;~~~---\------~~~----------I--~;~~~--I~~~=I--~;~~-- 100-035-0 023-20006-00 S BARROW 12 060 FEE-NSB +--------------------------------------------------------------------------+ -~~~~-I-----------~:;;;~~~------------I:~~~I--~:~~~~~-------I~;~;~I~~~~~~ 131300 NORTH SLOPE BOROUGH 890 ARCTIC SLOPE ON +--------------------------------------------------------------------------+ FLDPOL FIELD AND POOL \ MULTIPLE POOLS -:~~~-I------------~~~---------------- ~~~~~~I~~~~~~I~~~~~~I~~~~~~I~~~~~~ 150500 EAST BARROW, EAST BARROW 000000 000000 000000 000000 000000 +--------------------------------------------------------------------------+ UNIT UNIT \ ELEVATIONS I DEPTHS INUM -:~~~I--------------~~~-------------- :~~~I~~~=I:~~~I~~~= -~~--I-~- :~~ 00000 KB 26 2287 2287 0 +--------------------------------------------------------------------------+ SURFACE LOCATION I BOTTOM HOLE LOCATION ~~~=I~~~I~~~=I~~~I~~:I=~~I-~~I~~~ ~~~=I~~~I~~~=I~~~I~~:I=~~I-~~~I~~~ 0023 S 1755 E 23 22N 017W U 0023 S 1755 E 26 22N 017W U +--------------------------------------------------------------------------+ LATITUDE I LONGITUDE I FOOTAGE DRILLED IPERMF SSSV ~~~I~~~I-~~:- ~~~I~~~I-~~:- :~~I~~~=-I:~~~I~~~=-I:~~~I~~~=- =~~:~ -~~~=~- 71 14 17.00 156 20 15.00 1974 2287 +--------------------------------------------------------------------------+ INITIAL I FINAL I CURRENT I REQUIREMENTS FRMI SALES :~~~I~=~=~~ :~~~~I~=~=~~ :~~~~I~~~ ~~~~I-~~-I-~~~-I~=~~~ =~= ~::=~~~ DEV 1-GAS DEV 1-GAS ~ ð~ 15001 +--------------------------------------------------------------------------+ _~~~;~~~~_I--~~;~~~--I-~~~~~~--I-:~~~~:~=:I:~;~~=~~~~I~;~~~~~=~l_~~~~~~_ 03/10/1974 05/04/1974 ~ I 10 06/11/1999 10512 +--------------------------------------------------------------------------+ , , 1<1~ JJ "-...... ....J....j ¡ 'J ¡........ í 1J-¡ U., J WELL £45 f Fte(J 12- CONTRI)90R , / I II.,¿ /! I?~ 1'1'/.-' REMARKS IP_~' F~;:;::ICG;?Th~~" OPERATION Ai REPORTTIME IDAYS IDAT~/~kr 1k~~#('4- ¡t1£J'¡- tlhA,-A,v ~l?A/f 7ì~J Q..v~ -:4/ 01 '¡'r.Ærv a-.,I ~ :¡?¡ t,,K /" ¡4A/.A--'~k. ,A1(%l'dJ,¡. ~UA;'¡ð.evf IofA'( cf S(;¡ h< /!u,.~'¡;t?S'1- ce~eJ db~A/ Z 7~'1 ~ f~t;~ ~elu/~ ~ A,/V~tÂ(~. Aller recet't/t'J c.~J Y'(?JUý-W kf. ~ J~ d ~ t¡Sò /ìC 1t:r'~øIll 4 A'/V,vv~ fVÆ- c/ó.rec:P I/V ./1f,,;:by;J tle-37J & ~e~r'~;J //9./'x C(2.~Pv'¡- I¡V~ ~ Ii,. /k4 ~t' dN . C.? ~ ~ I? .? a hr.5 CI/"" ~ /If:, / ~ . COM/kk wfP/lieJ ~ ~ /~~ /fJ 'c~7"4dt:æ ( ~/Æã- w;-// b /1".Jf4/kd' æ4 ~ 4 ()(;. cc I"~JuÚ¡;I?~' . BARROW GAS RfiDr o CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK Weather I Temp. I Chill Factor I Visibility I Wind Vel. I Signed ()., Report OF of miles knots v</ ß )þ7~ .J .. .. '1'elecopy No. (907) 276...7542 October 20. 1988 Brik Opstad North Slope Borough 3201 "C" Street. Suite 602 Anchorag.. AI: 99503 ReI· Final Location Clearance, North Slop. Borough, South Barrow Well 112 . Dear Mr Opecad: On AU8Ust 16, 1988 the lorth Slop. Borouah(IfSB) South larrow (8B) 112 well. location was inspected by our r.pr....ntatiV8.·. . A meeting was held with you and Gary HaDIIBOl1 in the (:o.f.s81_ offices on September 22, 19a8to d18cusaadditionálworll to be done on the location. By letter dated October 11, 1981 you prond.dthe CODIID1aa1on with photographawhich abowed all additional work to be.ompleted.. The COIai..londeh1:'mine. the location ..et. requ1r....c_øf 20 MC 25.170, and hereby approves final 10cat1o.n clearance £:011\ the NSB SI 112 well location. S1nc.rely, (-- )i1 . /i;. ... \ // (¿ýJd · L~~'~" Coatsstoner Jo!A.IW>.78 ~, , ·~f"'::.~ ·:<'>'·"r'";,-~,:.,.-·~,,,,--"øi\¡". ~;'-'_",",':__i--,'-- .. ~:., '" --( í ¿a: NOItTl1 SLOI-E BOIIOUGII DEPARTMENT OF INDUSTRIAL DEVELOPMENT BARROW GAS FIELD DEVELOPMENT 3201 C Street, Suite 602 Anchorage, Alaska 99503 Phone: 907-561-8820 Mr. Lonnie C. smith commissioner Alaska Oil & Gas Conservation commission 3001 Porcupine Drive Anchorage, Alaska 99501 I f). / '7 w S 8 .:.;.- .. . Re: Photographs of Various Barrow Gas Fields P & A Well Locations Dear Mr. smith: During our September meeting you indicated that it would be helpful if we provided the AOGCC with photographs of the final site work around the Barrow Gas Fields wells which were plugged and abandoned this spring. ,. Enclosed are four (4) photographs of each location (SB #5, #7, #12 and #18) taken immediately following our recently completed grading of the sites. In our opinion these locations now meet AOGCC guidelines concerning restoration of abandoned well locations in actively producing fields, and we respectively request your final approval of this work. Please let either Gary Hammon or myself know if you have any additional questions concerning the condition of the sites, or any other issues related to this matter. Respectfully yours, Erik A. opstad Geological Consultant North Slope Borough f . I'· 'I ' I ' ;' " R)' ¡, ¡. l , \, J. I . ~ \ r,ë't l..;. ~ \~ t... ....,,' UC ¡ J t( cc: Well Records .' I::) O¡I & (':1': C"w:. CC'/;)I1)Ì,%!on "' M·EMOR~~J2lJJY1lm State or Alaska GAS CONSERVATIon COHHISSION TO: Lonnie C. Smith/( Commissioner . DATE: September 2, 1988 FILE NO: D.ADA.015 TELEPHONE NO: THRU: , Hichae IT. Hinder ~~/ @'. Sr. Petroleum Engineer SUBJECT: Location Clearance NSB South Barrow No. 12 BarrOv.l Gas Field Sec. 23, T22N, R17W, U.N. FROM: Doug Amo~=.fQ) Petroleum Inspector Tuesday, Aug~st 16, 1988: I traveled this date from Anchorage to Barrow to con3uct the location clearance inspection on North Slope Borough South Barrow Gas tJelL U<,. 12. As the attached photograph's and AOGCC Surface Abandonment Report indicate this location has some \'lOrk to be completed, gravel ,;oms removed from the pad and used for road repair. This left the pad area in a very soft and muddy condi- tion and at a much lower elevation then the marker post area. Therefore, I recommend that this location not be granted final clearance status until the pad area is repaired and another inspection is conducted to verify this work. In summary, I conducted the location clearance inspection on North Slope Borough South Barrow Gas Field No. 12. There is some remaining work to be done to the pad and I do not recommend that final clear- ance status be granted to this location until this work has been performed and verified. Attachment September 22, 1988 Final approval pending. NSB to remove barrel around marker, fill and grade around marker and grade rough area of pad. Pictures showing completed work to be sent to AOGCC. .,' 02-001A (Rev. 8185) Date Downhole P & A )J /If ¡Jnchò Y'£] 7 e I )1-J: I qq s t') ~ Pemit No. A//r1 API No. 50- ¡) 2'5 ~ 700 oG, ~OO Unit or Lease Name :SoIATH ßlJlê.Æ!bw M ,F, ({ell No. f /2., Field & Pool baS+ f?4Y¡/(}W held 20 AAC 25.120: h'ELL AßMWON(¡E~T ¡'u\l\KER: Dia. Steel Post (4"Hin.) 41( Length (lO' ~fin.) 12'.ð 1/ He ight Above Final Grade Level (41 Ì'!in.) ! 0 ( 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 2. Ft. ,/I in. Side Outlets: All Valves and Nipples Removed ve..> All Openings Closed ~, With Blinds , \{ith Cement ~., Other .I\F¡\CE M3t\NiJC'..'II:NT lŒJ'()I\T 20 AAC 25, ^R·fICLE 2 . FILE INFORi·¡ATION: Operator . N, 5, B ' Address 32é// êll Sf-. Surface Location of Well 2.3 F t. F S L, '''7 5 S F t. F G L, See. 'Z3> , T;;; {: &, R 17 kL, .i:L M. \-;el d s l.--- r;IFORI·1ATION BEAJ)\-;[LDED [) I¡¡.I~CTn Y TO NA RKER POST: (List ¡.,There Operator Well Number t·¿", Ft. Different froGl 'File NISI E. /7 FS L, 1'7'$6 Ft., Unit or Leose Name S;;¿,.(7f! !3lhf!Ra'" . Surface Location of Well: F L L, S e c ZJ. T Z 7 II ) R I -7 M, .!::L¡'1 Informa t ion) 20 AAC 25.170: LOCATION CLEAN-UP PITS: Filled In ____, Liners Removed or Buried 'Debris Removed / / ~ SURFACE OF PAD AND/OP, LOCATlO!:: Rough~; Smooth , Contoured ,Flat ,Compacted , Other rC-¡rCtu¡:; ( V'lClS 6-eeVl Y'é!Vþ)()../ed --:¡c;- do ¡/'~d Wt:Jyf< lA/"ffl, CLEAN UP OF PAD AND/OR LOCATION: Clean ~ Pipe Scrap , Iron Scrap Paper , Other ¡.,rood ~1ud , Cemen t SURROUNDING AREA: ¡.,rooded . Brush Sand , Other Tundra ~. Grass Dirt Gravel CUr--;OITION SUR~,OUNIJINC ARE,\: Clean -L Trash from Si te Other , Tre0S and/or Brush from Clearing Site ACCESS ROND: Dirt ,Gravel /, Ice , Other COND TTION ACJ,::k:S S ROAD MW Clean ~,Rough , Trees and/or Brushf[ë;m Other SURROUND HiG: Smooth v-:::: Trosh from Opcratlons Clearing Road , Spoil from Clearing Rood REMAINUiG TO BE DONE: 5 11/}û edt/) f~ J fIJ ke l-e RECŒU·1EtW APPROI/.AL OF MA:'Wmit·1Etfl': Yes / ,/ ')" I i-1 iiJ./I" r~ I I" ~. l/tt¿ No Final Inspection INS PECTED BY OS/26/81 t::. ~.I.J\. , ,\ ~. t" \''1\'\;\ X \,.,...-. . \¡, DATE 6/ /~ /B~ ,; b,t:; ~ i-;...... ~ .~. ~ ! f..-... "'Iri> P!ilÎ~ ~~. ,.....- '----* " rtA ~.,"" r : , - K: .. ~. ~ ,. ~~.,~ k' , t }-~: .. r:·, f"' .' f..:, . r.t1~ r- ~ ~ t , I ¡ I 1:::::. ~ (. -?.... Î '11\ (¡ ~(2J \~ ~ \0/ , ~ N J, c>- o "'"1;. £:" ~ "~ ~ \~ ~. .J7 tþ y _~"'J 0 * <~ ~. <~ \ ~'g..~ Q \, ~ \ I ~ ~~ "'_ ~/ \. I ~ " ¡ /. I <' f I ¡ ! i , . ' I I I I "" ¡ .~ /"~ i ..,....-'".,~ . I r//- : kJ ,~ . i i I ¡ I ¡ r ~ ~ c:: "~MEMOR~N[)8M . State~fAlaska . ALÂSKA OIL AND GAS CONSE.VATION COMMISSION Lonnie C Smittv1&./ .. DATE: June ~2, 1988 C01lfJ1isâioner \: TO: . FILE NO: D.ADA. .117 TELEPHONE NO: THRU: Michael T· Minder~dk SrPetroleum Engineer SUBJECT: Location Clearance NSB.SBU·12 ¡ 18 East Barrow Ga~ Field FROM: Doug Amos~À.J ~ Petroleum Inspector :j .~, Tuè,day. June 14. 1988: I traveled this date from Anchorage to Barrow to conduct the loc.at.±on. clearance ~. ~~p. s ..ection on the North Slope Borough East Barrow Cas Field wells+"" 18. I wall unable to conduct a complete inspection on these two locations because of the snow cover. .1 was able to inspect and photograph the well ...band()(11B8nt marker post. Roth marker posta were 1ncomplianc~ with the applicable AOGCC regulations. I wasasllured by Gary Hammon that as soon as the weather permitted any debris on the location would be removed, and that he would contact our office· to· schedule another inspection when the work had been completed. I filled'out an AOGCC location clearance inspection form fQr each location. These two forms. along with the photograph$: of the marker posts, are attached. In s\11llmary, I conduc.ted a partial loc.ation clearance inspection on the North Slope Borough East Barrow Gas Field wells 12& 18.1 was unable to conduct a complete inspection bec.ause of the snow cover on the locations. Attachments -", 02-001A (Rev, 8/85) .I,...\";'¡þ '.. :,\CI~ M)I\i\i)L'·:~II':NT lŒl'm\l' o AAC 25, ,\I([ICLE 2 , ) d L!~ I NFORi-1ATION: Operator ;JðRn-l. .stopE ,BOI!:()¿¡4H Address aZOj ß _c::;j-~¡gef âI1f2hdYt:¡tJle Surface Location of Well I Z Z I Fe F S. L/ J iSiS I (Ft. F -.£..L, Sec. Z3 . T Zz, &. Rn Id, ...kL~1. . p,e...AWlCS: 10 - 14- Date DOI.Jnhùle P & ^ ai/siBS C)c; -s. P :3 Pe llll it No. Un KI1t!) lA/Y1 API No. 50- ()Z3 -ZOOc:!}iP-ö" Unit or Lease Name S(Oun-1 ~A-~ t.J \~ell No. /Z,_ Field & Pool 64'S; J!5"¡t:¡/Z/2.I:)W ñ":::;"'/)J 20 AAC 25.120: h'ELL ABANDO:~~!1':::H HAlZKER: Dia. Steel Post (4"Hin.) +/1 Height Above Final Grade Level (4' Min.) Top of Harker Pipe Closed with: Cement Plug Set: On Well Head . On Cutoff Casing Distance Below Final Grade Level Side Outlets: All Valves and Nipples Removed All Openings Closed . With Blinds IìJFOPJ·1ATIOt~ BEAJ)\';SLDED fHHCTr:L Y TO MARf~r::R POST: (List \-lhere Different from 'File Information.) Operator No '5 5Di2.CìV\{:::\(...\ Well Number '} 2- '¿..'L Fe F-2-L. I1'5S --z.., \ Length (la' Min.) '8' Screw Cap , In Concrete Plug -z...1 Fe <::) If in. V- , \.,'ith Cement V-. Welds ~ 1--- Other ~énA. T 4- t3l-\12..eow Unit or Lease Name . Surface Location of Well: F t., }'...É:..... L. S e c 2.; , T --2.1 .J.L, R --1l w , ~a 20 AAC 25.170: LOCATION CLEAN-UP PITS: Filled In , Liners Removed or Buried SURfACE OF PAD AND/OR LOCATIOt:: Rough _, Smooth Contoureù Other , Debris Removed ~ 0 Flat , Compacted s~ot.J 'Z. , CLEAN UP OF PAD AND/OR LOCATION: Clean . Pipe Scrap ~ Iron Scrap ~, Wood Paper , Other SURROUNDING AREA: Wooded _____. Brush Sand , Other Tundra ~ass CUNDITION SURROUNDING AREA: Clean . Trash from Site Other Hud . Cement Dirt Gravel , Trees and/or Brush from Clearing Site '? '5~ 1) k.J ACCESS ROI\D: ./ Dirt Gravel ~. Ice , Other CONDITION ACCESS ROAD AND SURROUNDING: Clean , Rough , Smooth ~ Tr;¡sh from Opcr;¡tLol1s Trees and/or Brush from Clearing ROéld , Spoil from Clearing Road Other REMAINING TO BE DONE: C \ e~ '" VI f . ¿z'+ t-ev ~ V'\ð1..AJ \S RECOm!E1m APPROVAL OF AßANDONliENT: Yes INSPECTED BY OS/26/81 ~lÅl ~eL ~ 0'1'" e... No V--Final Inspec tion DATE (" It ~ I ß~ (1.........., i:~.. ~-- ~. I i ~, ~-.;..... f;~~.. if.,:"~- r-- "-- " r~ ~'". ,... , ----. ~ ~ IIIIIr r.~- r/ ff"., '. ~ .... f.... U. k. I ~ ~ f i:::=: 6RISI . STATE OF ALASKA ~ ALAS. IL AND GAS CONSERVATION CO~ ON APPLICATION FOR SUNDRY APPROVALS r " 1. Type of Request: Abandon..... SU·P.nd 0 0po"'''on Shutdown 0 Re..n,o, sUSponded well D A/t" c.slng 0 Time extension 0 Change approved Program 0 2. Name of Operator h Sl B 3. Address 3201 "C" Street, Suite 602, Anchora e, Alaska 99503 4. locallon of we" at surface From Umiat Principal Meridian 22' FSL & 1755' FEL, Sec. 23, T22N, R17W At top of prOductive interval As Above At effective depth As Above At total depth As Above 11. Present well Condition Summary Total depth; measured 2285 ' true vertical 2285 ' t:l- 16>. Plugging D SlImulale D PUll tUbing D Amend o'd" D Pe,'orate D Othe, D 5, Datum elevation (DF Or KB) KB = 26' 6. Unit or Property name South Barrow 7. Well nUmber 12 8. Permit number Unknown 9. API number 50- 023-20006_00 10. pool East Barrow Field Effective depth: feet feet Plugs (measUred) 2088' /lsAc'e, ,.0-( '- (¡ ,..., J:?O h{S f7 0 ~.~ 1· d> ~s n II_AI' ! Cif) f'iI..;t..J'" measured true vertical 2088' 2088' feet feet junk (measured) None Casing Structural Conductor Surface Intermediate Production liner Perforation depth: Length Size Cemented 20' 24" Unknown 145' 16" 345 sxs. 1062' 10-3/4" 950 Sxs. 1870' 7" 618 sxs. 201' 5-1/2" None measured 5t" Perforated liner 1900' true Vertical As Above feet Measured de~th._. . " VT~ , bVertical depth ~~tttl t 34' 34' 160' 160' 1076 ' Co¡~:r 1884tska 1884' 2062' 2062' - 2062' (est. by Gruy Management) TUbing (size, grade and measured deplh) 65 j ts ., 2-7/8", J _ 55, 6. 5#/ ft., 8r d @ 2053' BKB Packers and SSSV ('ype and measured depfh) Not Reported 12,Attachments Description Summary of proposal Detailed operations program ~ BOp sketch rø-- 13. Estimated date for commencing operation 14. If proposal was verbally approved Date approved ·~lru" and Correct to ~:l'.he b.~~~J. st f m. y knz ~7..edge ,L Titl~~&"767~ Commission Use Only No'ify commission So represenlaflve may witness Approvat No. 18: Plug integrity 0 BOp Test ]iõ Location clearance ~;c...J\;..4$ Copy ....... .3 --/7~88 March 15, 1988 Name of approver 15. I hereby ce Conditions of approval ORIGINAL SIGNED BY Approved by LONNIE C. SMITH 70rm 10·403 Rev 12-1-85 Commissioner Date 3-/¿;J-Pr 8-/0f by order of " the Commission DateJ ~I ¿, -0'8 Submit in triplicate r · NORTH SLOPE BOROUGII DEPARTMENT OF INDUSTRIAL DEVELOPMENT BARROW GAS FIELD DEVELOPMENT 3201 C Street, Suite 602 Anchorage, Alaska 99503 Phone: 907-561-8820 SOUTH BARROW WELL #12 PROPOSAL SUMMARY AND OPERATIONS PROGRAM March 10, 1988 Proposal Summary Well #12 was originally drilled by the Navy as an exploratory step-out to test an anticlinal nose similar to the productive structure in the South Barrow Field. The Barrow Gas sands were found to be marginally productive. Most available data on this well has been obtained from a "Drilling and Completion Report, South Barrow Gas Well No. 12, NPR No.4, Alaska", dated February 28, 1975. Well #12 is currently on production but produces at marginal rates. The surface facilities are old and require steadily increasing maintenance and could pose a safety problem in the near future. Since this well only marginally contributes to village gas deliverability, and may become a safety issue., £e feel that abandonment is called for.~.~\,\:\'4t.U General Operations Summary To abandon well #12 we intend to employ a quick and simple procedure as follows: 1. R.U. Halliburton, circulate permafrost cement down the 2-7/8" Tbg and up the 2-7/8" x 7" annulus to completely fill the entire hole volume to surface with cement. 2. Close annulus and bullhead 50 sxs. of cement into the formation, R.D. Halliburton & WOC. 3. Observe wellhead pressure, remove wellhead, cut off below ground level and install "Dryhole" marker as per A.O.G.C.C. regulations. We expect operations to commence on or about March 15, 1988 to be completed in less than 24 hours. - . .. . ~.~ ~-_.~.-. . .,'. CD -0 'r , 0,·, ,~ tl?- }, l h . .__.J[..,. .' r .. . .., j' lJ ·,Ht[J)<Dó. ' l i . r ."} ,- . .' \. '\\~ tc. \) \t \;. \, \:. I' SOUTH BARROW WELL N! 12 WEJ-LHEAD SCHEMATIC . , ·;·~·UYM~~~~~~~í ~E'R~I~~ c_~..J ~/~.~DlV. I ~~~~,_B.- ., i~~~ R~~-_ _ __1~~T~:'~.- ~~~1~J ~~_G._~P~- ~1-~!2--- I - NORTH SLOPE BOROUGH DEPARTMENT OF INDUSTRIAL DEVELOPMENT P.o. Box 69 Barrow, Alaska 99723 Phone: 907-852-8600 !'-4G\/2ifnbe'r r. '.!.'~)'.¡;.'~.'f,.;¡~'--,.._- "'<\'~h'¡'V' . C;li~~/ir~;,f~ m I (-"'''''\'11, "_'~', Ii---- ." ..1,.' '.'" ... 1\ II.. . ""0'" V ....:...."..:......."~'- , '._~ J '.j .,_....;j :i:,~-,;\Jr~: -.- '::;-~ :'::S:2~Ü ..'.........."....,.,~ ...... ..'" ,~~ -." f ~;;\¡C~-~~\SS J'"-" ~.~ T .\ ;'"; 'I· "'c' '-,-'- .."'" . ,: ,"/-·11 /,·~T!~£Bì- i ,;--:~ 4.Á-ao 1. ~tö f ~, -_.~- f·::¡UbLL 3(1(:11 F;orCLtoi ne new-"; ..."..-. ¡J.J. ,¡" T~ Anchorage, Alaska 99501 ¡:-::rttn: t'r1r;oo Lanni e 9mi th DE'-ar t~1t- ~ 8mi th:: ...--.- Please find enclosed Steve Hubbardrs~ November 2, 1987~ memo describing the wellhead damage ar1d kill procedure of EB #12. Ine NSB·s long standing policy of work performed in the Barrow Gas Field to be directly supervised by a gasfield operator or NSB company man was overlooked in this case by the contractor. However, the situation was quickly controlled and emeraency procedures activat2d~ l."'~~,n-:.-c..;,,':': ~ '-" ~ "-,._,,-,, In addendum to Mr~ Hubbard~s descr-iption, the well was initially the flare line an the casino side oocosite the -- , damaged nipple. Fluid was brought to the surface freezing n ~ne bonnet at the leak, essentially stopping all escape of gas! mak1ng the ar'sa much safer to wDr'k around. The estimated gas vented is approximately 5 mcf~ A protective cage made of u pIPe was placed around the exposed wellhead to protEct it from Dossible damaGe untIL a permanent structure COGld be instal1ed~ I compliment the men and equipment utilized to control ED #12. The job was performed with a h~nh r'egard +or sa+sty ana Droceeded s,~noot ~'11 )l ~ If there are further questions concerning this incident please feel free to contact me in An~horaºe at 561-8820. -. - b.1f1CEr-ei '1/, .'¡f{;I~~ £). ed~~ Kenneth D~ Wolcott Manager, Barrow Gas Fields __Ii; Dennis K. RD~2~ Ted Ale;'¿\f1der~ BARROW GAS FIELDS P.O, Box 69 Barrow, Alaska 99723 Phone: 907-852-8600 KUPARUK INDUSTRIAL CENTER P.O, Box 69 Barrow, Alaska 99723 Phone: 907-852-8600 RECEIVED NOV 1 6 l':Jbl Alaska Oil & Gas Cons. Commission Anchorage SERVICE AREA TEN Pouch 340044 Prudhoe Bay, Alaska 99734 Phone: 907-659-2635 ;. ~ I' MEMORANDUM TO: Kenneth D. \,Volcott, Manager, 8arrow Gas Fields Industrial Development FROM: Steve Hubbard, Field Superintendent Barrow Gas Field Development DATE: November 2, 1987 Industrial Development SUBJECT: WELLHEAD DAMAGE & KILL PROCEDURE E.8.#12 At 11: 00 a. m. on October 29, 1987 while I was on my way to the east field for well house removal on E. 8. #1'2. I stopped at the southfield office. At 11: 30 a. m. Russ Wimmer, J. V. Field Coordinator, reported that while trying to break the wellhouse loose from the piling on E. B. #12, the forklift driver had caught the annulus valve and nipple makeup on the wellhead with the tip of th~ forks bending the nipple in the wellhead and causing a gas leak from the nipple. All equipment was immediately removed from the location. The road was secured and the Fire Department and Public Safety were advised. I notified Carl Grumbles with UAS/ ASI and Ken Wolcott in Anchorage. Equipment and personnel were mobilized to kill the well. Halliburton was flown from Prudhoe Bay by Cape Smythe. The necessary equipment was brought to the field for killing the well and piping plumbed into the tree. A flare line was layed to vent gas away from the well. Halliburton mixed 180 barrels calcium chloride at 10 ppg to pump down the tubing to kill the well. Initially bullheaded 34 barrels into the well and opened annulus to vent gas. Circulated well with 116 barrels calcium chloride. Pinched annulus valve for back pressure on annulus, with calcium chloride returns to surface after circulating an additional 20 barrels. Shut down and observe well. Gas migrating to the surface. Decision was made to allow gas bubble to bleed off overnight due to darkness in the well house and extended amount of hours the men had been working. The following morning the well was still loaded with gas indicating the cement plug é!b,ove the argilite was allowing fluid to escape' from the ·well causing a underbalanced condition. Halliburton mixed 200 barrels of 10 ppg calcium chloride and had a 20 barrel pill of loss circulation material readv to spot. Pumped 85 barrels 10 ppg calcium chloride holding back pressure on annulus valve before vented gas from well stooped and fluid was at the surface. Spotted 20 barrel pi II of loss circulation material down hole and chased with 20 barrels of calcium chloride. Observe well for 15 minutes. All indications that the well was indeed dead. Proceeded with changing out the nipple and valve assembly. Secured well and rig down equipment. RECEIVED NOV 1 6 J.:.Jv/ Alaska Oil & Gas Cons. Commiss1N1 - Anchorage . I t.rc;»r - :~.~ - ;37 T H ÍJ 1 :":::~~iÞ.L~ .¡~ .1.í :,¡J ,~'. .:: .¡¡ :;~ .:. .\ (I(T 2'3 '87 17:..t=,: .. '. --. (:. I:: t.: ";~I"::'¡r': !·Ir.-r-~.~;: /: -." ¥ .'- . ,.~' .~:':~~4~\*~~~~~;~ ::,.... .' _""-","~,:J"",, __'. _~ "'........ .. ;. ,..,: :~,~~~::..~~t:~_ ~~~~..,:.;~~. .=:::.. ,. ". -. 7·;.:O~E~~i!: ~-.Un~tëd · ,_. : ·':";~;t,~I~~~r;i?i·€~·:'·' ·:;~i~.5E NAMEA~"D -W£¡.L· NO. : .~ ::.. .,~.~~~ ::~~f;~.~~.'" '~~'''''t-~''~' G¡;.U¡ ~!A.'~M;ZE't:iì ~¿~~.·:(fS co, 250: CED;.R SPRI:~~;S f.o.....¡j DAL:AS. 7EX~S 73201 ~:- ,", . . '." .. ..' ~~ ~... ". ~._. ""-.-. ". -'''.-.'' ". ....~ .. .r¡¡,gf~ l' of" .~ '';'. ",.,; "." ;-!>ötoi.: 8i~1.-';·~¡ -.. States' G~olo~i.c;¡l...S~~ey·· ::..;..' .:~...... ..~.: : .' . ØAR '. .: '.... , '; ":... , ,- !fl'_Gi$'f!ElDS .,...'..:.:., ¡;·~:·:,·:f~:·'·:: f· ;' ··;'E '.:"'-':'<':~'---:.'--~ -. ,-', ",~.'-- :,', ' ~~.: ",,~-I'~';-' ._-:"'",."~ "... ',,- .> -. ,-",' '-,"~:' ..'- . ,-,._,..,,-~'...._~.-. - -'..... ''''-';''- "- :.:.~-,~~~~. _"'"/~~;;_ ~:~:;''7''::"J\.~: ,- , '7 - ; _._.~ ',. "';' .. ·s. Blirrow ~~ .~~~~12 , . . .~. ~ . :'":-~- "- ~. '".. ).... ~,!- " ~- ...,.....:,..: .c"rEL%) : ·S. .- :",'.. ·"'-.t.-·:~ . .. . -- ..-~~"~. ~ . ~. -,.~.. ~O"'. .. . . 1 .22.8 FS1'& .17.54.9.' ..... .,_......;." ..: ._~-_::;/r:r.:.~ _ . ';'," ::':~"':;_·,;:l~.7:~.5..Ù¡.~,~;':c:·· '" -.. "h'.:.:~~~.~~~,;./:,_.. . -. . - -- .-. - -. -- - . --. - . ,;.,~: :....'7,':'" '''¡;~.''''~_.''' ,:.. . .~·.~COMPLETIOS ù.~TE' ANn PÒTE.:.qTIAi='"-:~~:S!4179.: ~lculc1t:ed .:lhsolu·~_e' ~~P!!n'~low ;:otelÙ:::'al _ _ ·~~~~~ff:::~fi~~;.~g~~~~J~{:~¡'~i¿~8~:~ ~", ,~~;,c~~;t~~~{~2;::~C .' :;"'.~~ \·!:D1ULLING CONTRACTOR: .~:'Paëifiè·:·Archi~ects àtid Engií1E:-ë:rs, -"Inc >w I:l::.vy :C.s.rd',¡eU. .,--~ .- .-.~..: ~~~",,;I...:_.....~-;.:-~:-::' ~... .'. "'~~'" .~., .~. .'..:;.. · ~.:. .. ,~ ;..;:..... ." ..'¿ <.>;, .:~,.;.:.". :::l.~odel '~ .~ri.111!1g _~ig No~· 3. :~~:~:;·:·;r~... .~;;~.;:~:":; '!-""::~'. .:.' ":.':~ F ~ '~~~: _: :!LSVA!ICt;. ~:~~:;iÈ~~ ~(t>: :;Ú~~;~~~: ~; ~:~.~;:~~~NT DA~!'. ,c1;I. ,. ',-:::,. +~ -~ ~ . . ~~=- , - -;-- "~"'..~' .- ~ , ., ,"; · ;'.." ,-:" t" .. ,'-.. ". .' -228S! .~~-';:' '¡"- ~.:-. , ;, '.. .-. - -< .:"\~' =-: . '¡..~ T",· .... ,-y,-~ .. ¡..--.. . . ,PST!;: 208S' 2062' u 'rop of ~',~ran&€: c!;:::ent ?e~leci ~<,-ú_·~ . bct'r.nm dE J.ln~!'. &.. .,-- ~ DF.P:H .. Et:../FT. G~1)1! rn ~t:..\D --- SIZE HG!¿ CE!·!E·~~1' '. " 24" .·16" lC-3/4It, 7" .5-1/2" . ,::~:t·..~:ò 20' c:. .- 160 ' " ·11JE-7'. 4 _ ~",._ ,-- . '. ," ..,:~ ·;:Un knót..m ~':::<6'N-SO __:·~··P-.5l. .. . Jlnknown , J-55 ,..... -''''' '. . ,:_:..~,~Pnknôwn _ '.<";~~:;;:'l5. ': ..:....Y:..:.:::.:;·.: :-;;.;;: 51 ·1884' :-:'....:,., ··?''''2- . . ... .. .- c·.,..·.' .) ·1861' -2062' ;~·.20 .....;. ·.Unkno'\\'t1 .' 8rd ;>.,.,,,..... -. Unknown XL .,. tin kn 0"-'[1 " e) :);~ I - ,,:, . I ill' ¡: - to , .. .. I . ~ 'r .:. i .;. ,i¡.!1 ·il .il .iJ !:; .~ í.I :. .. -.. -. I" .' 'P7 ~~"=8-...:.t, :(~·:;·.h:'·~I-::~- ,.'; L ~ ;':;I:=:;~J,'1 ,._-':~!C~T .-;: 1 :- :.~:' - . GR~¡ 1"'.ANAGt!oir.~~! SEit"J¡Ç=: ro" 2501 CE~¡.R S?R¡NGS RClAD DAL:A5. TE~~S 75201 ,. -". . _.~..-: '. ._'.w ~ '. . "'f' ~ ,. '..oes INTE'?TJ.,\ :. '---'''-'- '.' Dual Ind~ction taterolog ProxiMity :a~-Microl~g Co:np ~m!:1"at edNê~trO:l-.Fo't"!:1a t io~1)ensity . Ccmpens¡ãtedFcl1n4=ion Densicy (CafTU!1a~Gé!.r:'Jna) Borehole CCt:1pl!na~t~dSonic: Bore hel eGeome try Log. Four- ArmgighR~solut;cn Ce:!'¡\!ntBond ~g .'.;',':' SaT'30lind ·Unt<t::ct..'t'\ r.;nkrl"w~ t:nkpcwn 1;nkno~ Unkr:cT..-n. Cn ~ nC"'..rn Un k;:: o'.:n ' . U1'Ikno\o.'T1 Unk~o"W!: ._-~, " ...~. <;> '" '-', ':_F~ :', .:~ .~: : . - peri()rát~dl1~:~:,:<:-J.:~~~·..( . . ,"'"',.-..._¡..... >-,-- - . 'Ii' '.:.'-. ~-. ¡ ~ .~'.-. "':'c-..~.t :C'. ;;~. ;":';;"".,,,-~-''''; :....:...:.,... .;~ :.;;:t~:~~;.RVÁL;" ~,~ - ::l::.: :.~: .'.~.~~. ~'-':. r:; .~ . ""'-'-. q,.. ...1.96... 498..., "~--:~:~,:<·:5}~~;-;·-·....::;~·-;....: ^ "-'-'. ,.' .", "f ". -->:-; . ~. ..,;"~c·.:..~'~vl -:;86 -201Ct. . .,. :'·"":-·''''''''20'' 6,· ··..04'-· , :_~"'. ._:: ,<0. .I. -:-4 i)' , ':··".~·:···2()46' -:-2076 1. 2076' -210¡ 2163'-2192' 2192'-2220' . ,. 2220 f -2250 I : . . . ',2255' -:2285 ' .-', ' No. .,';'--. Core COTe :lo. Cor1! ?~o. Cöre ~c. Core r;o. èCùre No. CoTe .~:o. Core t\v _ ·Core ~t). . - -- --:. - I' "ÎÅRRoVlGÂS fIElDS FI If ~-, ?.:g.: 2 :ìf , ~4t.:r~: Ff....1S//·~ SERVTC~~ (.;û. ---- - ~..._--- ~~)J"" "'t'~ .,:,,~="~::...'~ :'." S,:hll.1mb:~:-8e.or .,.. . S(:h"".1~':'t?r~e.:- : Sch1.umbe't'gp.!., . Sc.hlutI'berSèr Sc::llJtt!:-e~ž~ yo ~chlu:nb~!:ger S .... " c.n.lI¡r:\C'Jerse'!' Schl \L'ubera~'1:" gchlu~t.t!rger :,:30 ' .30' 3"" . '.5 ! C1.1t' 28' 30' 30' rtéco.very -100% ~c:)"Jery -;'10m; R~r.ovp."t'y ..;;. 100: P.f.:('c.-ery '-"100i:Rocove:-y 29 t ~Rer:cve~e¿ 25~ 100 ~ i\"'C()VP-T: lGG~ ~ecovet'Y 10Q~; Re.cfJ....c!::y REcaV:::RY DR1:1.'i.- ~ '1 í-~t ~;;t5 .._---.,...~~.~ ----- . t~TE~'t.\L ----- . . :;C;T ~:,. 1 D:;! ~::') . 2 ,,<=''!' t:n.. 3' _.~, .. D~'¡' z.:- l¡ ~. 18~5'-198St 1985' -21011 1946' -:n 01' 2100'-2250' Not: aV,c!ilnhl ~ Packarhi le.~ PaC'ke::r fz~led . Not a....<i:..:.able 'r/5~ B:jr:;~~ 17:52 NS81E LIÄISON. OFFICE· P.3 CRù~ }~\AGL~ENr SERVICE CO. 2501CEDARSFRINGS ROAD DAlLAS, .TEXAS 75201 . . . Page 4 of 6 Date: 8/15/79 REMARKS: Most of the data ccmtained herein,. excluding well head equipment: , was obtained from a repot"t pt"epared for the Director, Naval Pett"olewu and Oil Shale Reserves dated Febt"uary28, 1975, entitled "Drilling and Completion Reportt South Barrow ðr&Þ \:œl1Nû. 12, U4v4l I'c:b:olc~'I. ncaœ1-VC: Uo. 1" Dch~~ðVt AlAl:Slu~. t. This well. was drilled as an exploratory step-out well .. to· test.. anant:tc:~inålnose similar tathe productive. structure in South Barrow field.'rheSouthBarrow Cas Sand (Jura9s~c)wa$ .found to be marginally productive. A deeper: sand (Triass1c) .. . . was found to. contain . oil, . but productive potential was considered submarginal ;-and . the oil zone was plugged back. The well was completed and ispresenrly shut-in as a submarginal gas producer . .. ,'" GRUY MANACE."1EN! SERVICE co. 1,2501 CEDAR SPRINCS. ROAD, . " DALLAS, TE..XAS 75201·· Date: 8l15/79. WELL HEAD EQUIPMENT: Casing bead.. 10-3/4", 3K psi WP slipweld x 10" 3K psi Rucker-Shaffer casing head w/2 - 2" LP outlets. Intermediate spool - None. Tubing bead - 10", 3K psi WP x 6",. 3K psi WP Rucker-Shaffer tubing head w/2 - 2" LP outlets. tree - See schematic. . - . . BARROW GAS : fiELDS f I L E .'.' N-SO, 75H/ft., casing to 160' .andc:emented Intemediate casing - Ran 29 jts., 10-3/4", P-Sl, SHE/ft. f '1'&Cc:a.sing to 1067' andcemencedw/950 ex. Permafrost deta:l.land float equipment unknown. ) casing - Ran 48 Jts. ,7", 23il/ft., range 3 flush joint/casing and ceUlentedwl340 5x~Permafrostcetnent folloW'edby278~sx. G ce1l1ent.· (Casingdeca11 and float equipment unknown.) Bottom Joint of liner orange Not cemented. TUBING DETAIL: KB to Tltubing head flange 65 jt:s., 2-7/8", J-55 , 6.S/l/ft., 8rd 1 jt., as above (pup joint) 1 jt., as above (pup joint) Landed depth ? ? 12' 4' 2053' 17:53 ,. ,.'XT 29'87 17:53 NSB-ANC.~~ u¡:.r·=(,r¡ ':IFF::::: , BARROW GASRHDS f I [ E .::. · · ...... ... .' ',.---f3') . . ---------.. ~ -~~~~ ~- ~_..r-< t ¿-. ?~ ---.- . . .. l t r t GRUY MANAGEM£NT. SERVICE: co. I p/L. DtV. tOR. J. B. - - . I c~n:.: 9-13-79 CWG.NPR-ï-ZfZ .,..1''''' -. ..;:,; ..~" "..i I 1'110 OCT 29 '87 6 J.I.-oJ·.) - .,J) .11- 011 011 '11 '11 t...r :::' ~I f , , 1!' . - WELLHEAD NO. 12 EQUIPMENT: .BARROWGAS-·-FlE[OS FI iE 1. 2" plug. 1. 7". ~1.hal1 vilvr 3. 2-7/8" EUE, 8rd x 2" 2-7/8" UNITED STATES DEPARTMENT OF THE INTERIOR . . GEOLOGICAL SURVEY Office of National Petroleum Reserve in Alaska 345 Hiddlefield Road Menlo Park, California 94025 April 17, 1978 ~-, '~~~,r;. ..'~,~, :¥'..v...., ~ ........... Mr. Harry W. Kugler Division of Oil and Gas Department of Natural Resources State of Alaska 3001 Porcupine Drive Anchorage, Alaska 99501 ~.." 'r~>,~ 1"1Y...¡'t, f':'¡' .. 0~· Dear Mr. Kugler: - We are sending you, under separate cover, sepia and blue line prints of logs on the follm.¡ing wells from NPRA: East Teshekpuk #1 South Barrow #6 South Barrow #7 South Barrow #8 South Barrow #9 South Barrow #10 South Barrow #11 ~1î~J3ãf;Q;¡:'\ ,"#ï2 (Ëastãrëã:t7 South Barrow #13 u' South Barrow #14(East area) ,.,...." . . ti:::' ~. ~p' '. Lists of the logs for each well are attached and those we are sending to you are enclosed within the red outline. The letters "s" and "p" indicate "sepia" and "print". These logs are not to be released to the public until their availability is announced by the Environmental D~ta Service of NOAA in Boulder, Colorado. NOAA will be the primary distribution agency arid their release of the data will be authorized by the Office of National Petroleum Reserve in Alaska at the proper time. t.:'~'... ~ ~" ~ . .:.It'" ' .. ' ¥;:' .~:;. Please acknowledge receipt of the logs and your under- standing of the release procedure by signing the attached copy of this letter and returning it in the self-addressed envelope. Very truly yours, to.-/! ¿J,. -¿-C¡ ~ ~ ,( Uûj../¡L-/ 1¿/ {¿2-1vÚ--y- r ~ t· ... iÞ:_~ Robert D. Carter 1""":; r/;/o/(?('I ~ dYJ ~·-u " 78 ~.vK ~;:;~~ ~'" ~"'.-~ ' e: ..... , . I .,.-- Page -L of 11 WELL NAME: South Barrow #12 ITEM TYPE LOG SCALE BASE RUN DATE lOG INTERVAL COPIES REQUESTED ~. 1- OIL 5 F 1 3-15-74 160'-1061' F~P 2 4-1-74 10761-22761 2. OIL 2 F 1 3-15-74 . 160'-1061 ' F~P 2 3-31-74 10671-2276' 3. BHC 5 F 1 4-1-74 1067'-22621 F~P 4. BHC 2 F 1 4-1-74 1067'-2262' F P 5. FDC-GG 5 F 1 4-1-74 1067'-2281' F,P ¡ 6. CNL-FDC 5 F 1 4-1-74 1067'-2281 ' Fìp , 7. CBL 2 F 1 3-18-74 1001 -1010' F~S,P ! 8. Mud 2 V 3-13-74 7001-2285' F~P : 9. Saraband 5 F 1 4-19-74 1080'-2264' Fip ~ I 10. Boreh01e- j Geometry 2 F 1 3-15-74 160'-1065' FJP I 1 1l. MPL 5 F 1 4-1-74 1067'-2279' F ip , ~ ~; ·.Þ . .it UNITED STATES / DEPARTMENT OF THE INTER'IOR GEOLOG ICAL SU RVEY Office of National Petroleum Reserve in Alaska 345 Middlefield Road Menlo Park~ California 94025 January 3l~ 1978 ( r . ¡·V'O R /'\ t I IJI. I '\"\ Mr. Harry W. Kugler Division of Oil and Gas Alaska Department of Natural Resources 3001 Porcupine Drive Anchorage, Alaska 99504 u"y:¡ ';1..' ~. )~..k¿.~ (.-¡" ~'-X.. _-d'.,", r . <"\ J~\¡~ ~- ..--:-- Dear Harry: The enclosed lists detail a lar~umber .Of chips from I-foot intervals in cores (South Barrow 2, 6, 9, 1 13) that we had assessable in Menlo. They have been shipped in ,l(f bo s as noted on the list. II' ~ Unless you refuse to deal so haphazardly, we will keep shuffling chips to you as we have a chance to sample. Currently~ most will come from Doc's work in Anchorage. Hopefully, you will keep a systematic record so that in a year or so we can mutually define the gaps in your collection and fill them specifically. Catching up on the pre-Husky material will be a big job that will be justi- fied by having your library as complete as possible for the succeeding generations. We'll be getting to the post-Husky cuttings and the pre-77 well material shortly. Regards, ~~ Irvin L. Tailleur [~ E eEl V E D FED - (3 1078 Enclosures D:víslon of Oil and Gas CUOSl;;'/;Uon AnOiJOtt'!QC I< 'Ø1r ó/lJ ~ ,.fV' ~r j.'J ¿/¿ ((10 ? , ¡: " ~ ~; "1.. ~ ~ t ',~;~::. I _,"'e; ~ ~~ ,/.,,--, ~'~"'. ... t·· ¡ ~ l' f. , l~ ø~., ~. ~'$~ r- ~ ..... .;.. ~!.... . ~:'" ~. < t . . ~ !:,';..:i. t, .- '~'!'~-.~.,~~ ¡ :.. ~1 ' ~......: ".,..~.¡,; h-:- ~ ...",,"t" ¡....'f{ -\.. F , ..~...~ ~1';>.'-"'~.""'. ,......J~.. 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UNITED ST.i\ TES DEPARTMENT OF THE INTERIOR GEOLOGICAL SURVEY Office of National Petroleum Reserve in 345 Middlefield Road Menlo Park, California 94025 Mr. Harry W. Kugler Division of Oil and Gas 3001 Porcupine Drive Anchorage, Alaska 99501 . Alaska . .~ V:J?}/ /1~ \'~/-;/ // , December 153 1977 Dear Mr. Kugler: In accordance with your letter of August 29, 1977, to Irv Tailleur, we are sending you, under separate cover, well log sepias which we had on hand. Two lists of these are attached; please acknowledge receipt of the sepias on one of these and return in the attached envelope. The remaining sepias and blue line prints of all logs will be sent to you when we receive them from Houston. A purchase order for this work is presently being prepared. Very truly yours, fu!u~L/ ~~! ¿:}0~~ Robert D. Carter Attachment nr' "'["\í7'r\ f". i- ( ,.! \! ¡- 1 ¡ \ ;.., ..... _. " '" '.. r~';, r. !"> (. fJ f~) ...-~ J . ,.:I( ,¡' D!\J¡~:~:!1 c( ',(; :1 t~ ;1: ~.¡,~ !: U fJ ~~,,",'::~'-;':',:~::''::'~-''" '-_. ~.'i-'~~¡C-.~ ~.-"'Y..rr-" ",:',.1f-, ". " ~.,;«:-:¡ <' _ 7< ~A'....~,~.,...;.. '-:1:..':' .."-,.;....;."'~,,:,j,-,-....~.,...:.'-~~..ft. K ---:-li\-'\ J i \ -l\ ~ 1^ ~frP 9-" 1) "QJv\....; ~. r'... ~. .~.'''''':o>...;...-.~ ",.,.._,...:..·.<c....' ..": "-:-1","-'.1""#,".' ··'Ii' ~..~.' ,.,."":.."...,.,.,..-, .. . '. . ....,.:,. .... ")I~.'''.:;;'. . .:,¡;).. '......"...~.....~¥'..:;þ/!'. .' ~..;;...-=. "'.' . ".¥"" /,J;If¡. "~'_~"'.~. . '.. "'.·~'.·Á..''"-Yr'...>~A!... ¥~~...:.~. . ~..... .~;.f'T...-r, 0·"":;"" ''Y~~"V'__.'''~';'' ... ",. ....;. ...........",r.'"""" . ...... . '... ,.' .,-,r",,-,"""" .'-.....~..;_~.T.:U":..'T..:...:'!....ð'.·~.'~·..'ii".L,~"-_:'I."". . , "~ ,T'.." ,," W'.IIft" -~"~.""':.'''''' ~~.:~~~ ....;¡-}F.þif>. '.~....."-'è-"f,,.,'J~..,.,.,:..- '" _....,.'......;:>'~ .. _. .......... .:, .,~., ,..~~.. ~""~, .---. ~ ~'1.-". ',~}.. ~.~,;..... \i."i;¡..;~. ..~,~, L ~ "'.. F'. ..... ~-..."..-.,. · r '5 .' ~,,:. ~ """.., .... , .,~ - · ~.-.:.~" ~ .. ......,,. ~-~,~~~- , ~: ..&.. .......~.....~, ~ ~~'r~";" ~.... ~-" ~'t~~,,- ......... - · _~~·~··;';'·___c·___,·~~..._,...___.___,__~ ~ .' .' ., . . Atigaru Point #1 Sepias .¡ Saraband J Cori band J Dual Induction· Laterlog East Teshekpuk #1 v Dual Induction - Laterlog v Boreho 1 e Compens a ted Son i cLog Cape Halkett 16N-2W-l vDual Induction - Laterlog vTemperature Log v Ca 1 i per Log ¡ Compensated Neutron - Formation Density v Cori band .I Compensated Formation Density Log ~ Borehole Compensated Sonic Log v Borehole Compensated Sonic Log ~Borehole Compensated Sonic Log t Borehole Compensated Sonic Log \. Dual Induction - Laterlog ~/ Cement Bond Log v Cement Bond Log ~ Cement Bond Log L Cement Bond Log ./ Mud Log v Stri p Log Iko Bay #1 VContinuous Dipmeter v'Borehole Compensated Sonic Log /Compensated Formation Density Log ¡Dual Induction - Laterlog V Borehole Compensated Sonic Log v Proximity Log - Microlog ~ Dual Induction - Laterlog Proximity Log - Microlog Cement Bond Log FD Log Compensated Neutron - Formation Density ¡ Mud Log South Barrow No. 12 Dual Induction - Laterlog Cement Bond Log Borehole Geometry Log Formation Density Log Compensated Neutron - Formation Density Proximity Log - Microlog Saraband Dual Induction - Laterlog Borehole Compensated Sonic Log Borehole Compensated Sonic Log nF··rc¡ I"~ ._ \... ~.. r: n L:. ¡ '\ í' ~/ i 1 ,_1 '. ,. J) ) I.) ¡ ! 'DI\'\::~;!!, ¡i -,~ r,: .~ _ ;;!':'-"\: 5" 5" 211 511 511 - 2" 2" 5" 5" 5" 511 . 5" 2" 2" 5" 5" 5" 5" 511 5" 2" 2" ~...; ~.':A~ ~;., ;. ·'1: ~., ,., . ~' "'/" ~' " .'~'. '. ~-.;.-:' ...' ~~o:c: rI~· ~:.- 5" 2" 5" 5" 5" 511 2" 2" 2" 5" 5" 2" ;"O::~" ~*' ~ ~~. 't,vJ.--,: ~ ~.. .-. ~.,~ . : . ..'....-:i"~ 2" 2" 2" 5" 5" 5" 5" 5" 5" 211 .. .....,¿;. ""'" ~ ~,..~--- ".~ ~.....~ ~$;~. r.:.:::=' - :+~~,.-~~~_~;::: ,'_-~f¡-~·':'~~~èþ~k~~;:<i~~~~ ~~$~~~~~,-1r~' ~·>t~~~,~~~~t~'\'~' '~~;;'~~;"":~~~'-j::-~:~~~~~~ Yf2ft!~.,':"-''''t., ..~.. ~.7"';~.,K"~"""~.' .Y':. r.k...~";'.~~:'-'....:4:k~Ã''f'.. 'Ã'"V~Y"""~~."&..r ~~..~:t::~, .~..~~.."..,.. -...r-~~vt~..".:.æ'.·"'..- """ "'<;'''''*''''~w. .",-y- 'cJ"'~"~;~ ~'-:.~-~~.~~ "i"""-:~~.,¡1I(~-.-I.--.., _..Jf.,¡._~"""-.eCI.:; ....:p,~~...~~..~.; .~~;", ~~:~,. . V e 11 urn South Harri,son Bay #1 2", 2 runs Dipmeter Arrow Plot v/ South Simpson #1 Dipmeter Arrow Plot 2", 2 runs Atigaru Point #1 Dipmeter Arrow Plot 2", 2 runs Wt Foran Dipmeter Arrow Plot 2", 2 runs West Fish Creek #1 Dipmeter Arrow Plot 2", 2 runs ..........-. V v V v ¡/' Vy/ . r---";. f1!..:. ~~~.. ":.:", , :,~ ¡ -- f'A-:';';>' Above material has been received and will be held in a confidential (proprietary) status until announcement of release by the Environmental Data Service, National Oceanic and Atmospheric Administration, Boulder, Colorado. r r- ¡ ¡ I fn L :;.: {¡ ,c:l/ Dh¡~~;0r~~f "";"1,:' ~~ (~t' I ,ú ., G1f ( ~~;; \~: ~:'"'\ t1¡..~~~r ~ ¿ ~-~..",.~ ft"":>.( ~. ~ ¡....- , - ~Â~: ;1:- ~.~... ~A:..'_t' ~. , . ...-.' ,........ ~~~':.·.-4.-~~~:~'"',¥'7'~~~¡r"'\._,...~~:,~,,~u-t"';·~"\~f~--"~~~:'" T~'<.,¡r-:-' -,:r",~~ ':~,,~~., :~':~,:....~_.. ~,: l~~·~J:·"ï;;:t....');tiI1:.,"¡¿"~i!::~:·'~" ~ , "~~"~I-'fi'--,~-,: ,>t, ..-~ ~r,,-r... '~,."'" ..:~^; .'~ _,~,..'~t;: }i..~Ù~.'"':~·"':~""" ..-tØil>"":,"";¡;' ..' .. . ~" <~ ... "'~.11f'. "'.. < . .~ ~.~..I;~:;""~.~,~,."",,,,:,,~..;.o...~..J".:.... 'r.r.~'~'f:.p:¡,.,J l. .'. .."....... J....,. ./ ' /~ ,: , t ! - DATE: REPLY TO ATTN OF: SUBJECT: i ~ e e· UNITED STATES GOVERNM ~'·'-'memOrandUI .June 6, 1978 ~~ TO: , ; )..,., .......~.- / ~···(~~-O;\-1L i_:¡c~~~~.~: __"._ "Standard" information on East Barrow gas f1eld__ "'--L.:"'.,,--"~.!-¿L., S';r::----~__ ~"".-_'.'~~.>;. ~-'1 }ts~~~9f~-~~;~'r' . --_.~~ ¡1L.lS: Several people are called upon to work with or to give informat~~~ East Barrow field. Formation tops vary a little from log to log. Produc- tion rates have been reported at varying choke sizes. In order to keep us all working with the same information and avoiding subsequent explana- tions, I have compiled the following for standardization. Bob Lantz, Seattle George Gryc, Chief, ONPRA, Menlo Park l~ Barrow well no. 12 ICXJ4J~- A. Top Lower Barrow sand 2031 (-2005) B. Base Barrow sand 2050 (-2024)::>- IS"OJ C. Top Sag River sand 2200 (-2174) i D. Top Argillite (basement) 2263 (-2237)/ ~ 3 E. Initial Potential, Calculated Absolute Qpen Ilow (CAOF) 360,000 cubic feet of gas per day. 2. Barrow well no. 14 IDO-D"3Tis A. Top Lower Barrow sand 2057 (-2026) B. Base Barrow sand 2080 (-2049) i C. Top Sag River sand estimated 2235 (-2204E)~/~~ esf. D. Argillite not penetrated E. Initial Potential CAOF 3,700,000 cubic feet of gas per day 3. Barrow well no. 16 J DO-03'1 A. Did not find Barrow sand B. Did not find Barrow sand C. Did not find Sag River sand (not expected) D. Top Argillite (basement) 2332 (-2302) E. Dry and abandoned 4. Barrow well no. 17 I DO -olfó A. -B. C. D. E. Top L. Barrow sand Base Barrow sand Top Sag River sand Top Argillite (basement) CAOF 7,200,000 cubic feet of water per day. 2102 (-2069) 2127 (-2094» 15""0' 2277 (-2244) i 2345 (-23l2)=>- '8 of gas per day with about 200 barrels 1% :Lo I DD-oI..f4' Bø...Se. L.Bct.rrow ..sd.. h ----...-.,--.--.- --T-'O ...---.-- ----.. "tt:p ...s-"¥j q..$>'~_ T;r.5~ R.1; ~. '7,/-' Buy U.S. Savings Bonds Regularly on the Payroll Savings Plan J -l~d OPTIONAL FORM NO. (REV- 7-76) . 10' GSA FPMR 14. CFRJ 50.0-112 ~ I?? /00 ~b *u.S.GPO:1977-o-241-530/3360 to ð -s hd II ow .p~~ $~ R. .. I . . 5. Barrow well no. 19 IOÙ-WI A. B. c. D. E. Top L. Barrow sand Base Barrow sand Top Sag River sand Top Argillite (basement) CAOF 7,200,000 cubic feet 2020 (-1990) 2040 (-2010) ~ 15"8" 2198 (-2l68).-r 2265 (-2235) > ~7/ of gas per day The gas-water contact in the East Barrow gas field appears to be at about 2111 in Barrow well no. 17. That is a sub-sea datum of -2078; highest structural point established on L. Barrow sand (well 19) is -1990, giving a gas column about 88 or 90 feet thick. Analysis of gas produced from well 19 indicated about 12% Nitrogen, whereas gas from well 17 had less than 1% Nitrogen. Well 12 had about 7% Nitrogen. The meaning of this information is not clear, but may be related to faulting of the Barrow sand reservoir. Additional information may be forthcoming from the high resolution seismic program of last winter, and certainly from additional drilling. Reservoir quality of the L. Barrow sand does not seem to vary widely among the 4 wells drilled to date in the East Barrow field. The thick- ness varies only from a miximum of 25 feet to a minimum of 19 feet, with downdip wells having thicker sections. It appears to me that well 16 may have crossed a reverse fault. I sug- gest you look at the Gamma-Sonic, and see if you think the section 1750-80 might not be repeated at 1930-60. Hopefully the high resolution seismic will also clarify the possible faulting in the 16. H. J. Gruy and Associates have proposed to have some special core analyses performed on cores of L. Barrow sand from well 17. The material will be shipped to Core Lab in Dallas this week. The information will serve to increase the accuracy of the reserve estimate of East Barrow which they will prepare in the near future. There may be a variation of a few feet on some logs for formation tops, and some of you may have already called a top at a different depth. If it is close, can we agree to the calls listed here? If you think the difference is important, let me know and we will argue about it and maybe change the call. If the tops listed here seem close enough to you who will be using the logs of these wells, we can probably save arguments and misunderstandings if most of us, at least, use the same calls in our mapping of the L. Barrow (top and base), Sag River top, and top of Argillite. Incidentally, I am a little confused by the telescoping substructure on Brinkerhoff rig #31; it was evidently 18 feet high on well· 16 (30-12 = 18); 26 feet high on well 17 (33-7 = 26); and 20 feet high on well 19 (30-10 = 20) Does anyone know the reason for this? 2 . . DRILLING AND COMPLETION REPORT SOUTH BARROW GAS WELL #12 Naval Petroleum Reserve No. 4 Barrow, Alaska 99723 28 February 1975 (¿l:~~,,~< 0.' ' ~.~~_/~ ~'&rliam Jac~ ~C< ~ ~ Drilling Superintendent R~aJV<qQ.~( Richard v.·~~r, P. E. LCDR, CEC, USN Officer in Charge ~""'\.,,,~ -..... Or At :...\\ .w~~~~oooooo..:0~þ~b~ p¿¡.., 0- .. """.,,'1., -... . ¡. 1/'. . . ,., '" '. ',,, . ,," ;1~o, ~,~.:1 Qð Ø*:49!JJ"~ o.*~ ~..ooooo..........o.o.oo~ ~ ~ ~. 0 0..... ...... 00000 0.0. ~ ~ ~\ RICHARD V. SHAfER If::! P I.;~.. No.3640-E .ooh ~Q ~ioooo 00 0 oo.oo~~ \\~ P1l0FESS\Q\\\:"'-- '-,,,,,,,,," T A B L E - 0 F - . . C 0 N T E N T S 1. INTRODUCTION AND SCOPE 2. WELL DATA 2.1 Data Summary 2.2 Wellhead Diagram 2.3 Wellbore Completion Profile 2.4 Drilling Equipment Layout 2.5 Location Map 3. DRILLING JOURNAL 4. DRILLING CREW 5. PERMITS AND REPORTS 5.1 Department of Interior Permit Application 5.2 State of Alaska Permit Application 5.3 Department of Interior Completion Report 5.4 State of Alaska Completion Report 6. LOGS AND TESTS 6.1 Production Test 7. GEOLOGICAL CONSIDERATIONS 7.1 Lithology 1 . I N T R 0 D U C T 1 0 N A N D S C 0 P E This report describes work done in drilling and completion of Well Number 12 in the South Barrow Field. This exploratory step -out well was drilled under the supervision of the officer in Charge, Naval Petroleum Reserve No. 4, by Pacific Architects and Engineers, Inc., for the Director, Naval Petroleum and oil Shale Reserves to test an anticlinal nose which appears to be similar to the now -productive structure in the South Barrow Field. The purpose of this well was to seek additional natural gas reserves in the Barrow area and test for the possibility of other hydrocarbons. The South Barrow Gas Sand (Jurassic) was found to be marginally productive. The composition of the gas is somewhat different than in the established portions of the field, and surprisingly high concentrations of helium were measured in the gas. A deeper sand zone (Triassic) was found to contain oil, but productive potential was considered sub- marginal, and the oil zone was plugged back. The well was completed as a gas producer. . . 2. W ELL D A T A 2.1 DATA SUMMARY FIELD: South Barrow Gas Field PROPERTY: Naval Petroleum Reserve No. 4 (U. S. Government) WELL NO: Gas Well No. 12 LOCATION: 22.8' R17W, State x = FSL, 1754.9' FEL Section 23, T22N, Umia t Principal Meridian. [(Alaska Plane Coordinate System: 695,850. y = 6,305,300 (zone 6)] ELEVATION: 26 ft. (approximate) ground level above sea level. DATUM: All depth measurements are referenced to kelly bushing top (KB). KB is 12 ft. above ground level. DATE OF REPORT: 28 February 1975 DRILLED WITH: Navy owned Cardwell Model H drilling rig No. 3 DATE COMMENCED DRILLING: 10 March 1974 DATE OF COMPLETION: 4 May 1974 PRODUCTION TEST DATA: Calculated absolute open flow potential = 360 + MCF/day. (See details in section 7.3 of this report. ) PRODUCING FORMATION: South Barrow Gas Sand. TOTAL DEPTH: 2285', plugged back to 2088' CASING AND CEMENTING PROGRAM: 24-in. OD Conductor Pipe, 1 joint, cemented at 20 ft. KB l6-in. OD Casing, 4 joints, N-80, 75 lb/ft. with 345 sacks permafrost cement. 10o/4-in OD Casing, 29 Joints P-51, 51 Iblft range 3, buttress T & C. Cemented at 1067 ft KB with 950 sacks permafrost cement . . 7-in. flush sacks class OD Casing, 48 joints, 23 Ib/ft, range 3 joint. Cemented at 1884 ft. KB with 340 permafrost cement followed by 278 sacks "g" cement. LINER: 5I;;~-in. Blank Liner, Security flush joint, 1 Joint, J-55, 20 Ib/ft., range 3. 5I/2-in. Slotted Liner, 2062 ft. KB, Security flush joint, J-55, 20 Ib/ft, range 3. Bottom joint orange peeled and spaded. TUBING: 27fa-in. EUE tubing, 65 sub and one 4-ft. sub, range 2, 8 Rnd T & C. at 2053 ft. KB. joints + one 12-ft. J-55, 6.5 Ib/ft, Tubing bottom WELL HEAD: Rucker-Shaffer Wellhead Assembly 10~4 X 7 X 27/a-in, Drawing No. SK-N-083 (See section 2.2 of this report). MASTER VALVE: WKM Steel Valve 2~a EUE 8 Rnd. Female thread SURVEYS: Schlumberger Dual Induction Laterolog Proximity Log - Microlog Compensated Neutron-Formation Density Compensated Formation Density (Gamma-Gamma) Borehole Compensated Sonic Borehole Geometry Log Four-Arm High Resolution Continuous Dipmeter Cement Bond Log Saraband Halliburton Successful drill stem tests were made at 1885-1985 and 2100-2250. Core Lab Core analysis was provided on various samples from 1966 to 2060 ft. KB' Reservoir fluid analysis was made on a sample from the oil formation. (Samples were taken by North Star Engineering) Petro-Tech Mud Log Bureau of Mines Gas analysis 2.2.ELLHEl\.D Zirk Fitting r . ' 2" x 10" Double Extra Strong 1\ 2" Nordstrom Valve, Fig. 2344 ,I F\ --1 10 - 2" Bull Plug, Extra Strong RUCKER-SHAFFER Wellhead Assembly 1034 x 7" x iVa"· Dwg. SK-N-083 /L Scale: 1" = 1'0" D I A G. A 14 6 - I '100 l I : ( I 3900 j ~ w -S:: I ~ ~,-J I I I Swage Extra Heavy 2Í'~3" OD EVE 8 Rd x 2" LP WKM Steel Valve #297592 2%" OD EVE 8 Rd 2" x 10 " Double Extra Strong r- 2" Nordstrom r=\. Valve, Fig. 2344 I r A 2" Nordstrom J r-----~ Valve, Fig. 2344 \ 2" x 10" Double Extra Strong 100/4" 49.5-lb. Casing 7" 23-1b. Extreme Line Casing 218" Tubing W ELL H E A D SOUTH BARROW WELL NO. 12 L:..:~____~i..J~ jJ_~~ _ B .'t"; C 0 l'Ii P L E 'I' I () le J.' ~< U 1:' I 1... E - _'_-'-_"-'~-----.~------------,--.~- . .-.-.-.---------------- D()[Jth~3, iŒ (feoiì 20 i C,O 170 :n" holo- 1 4 3/4" ho I e 1067 IOF) ¡ 13 (, i ì ß ():) leD4 205.3 ') (..... ~~ 'J ¿.uu,._ ?OI:~I¡S ? I 'JO '-)') t.- ç. ¿_L .)_) '7 ';/ . '/f¡" core ?2ß7 9 %" 1'10 I () ~ " ¡'I -: .. .' (, ~ :~{Jk?(:ø& ~. holo (no scaio) ;Z4" Conducior', I Ji-o ló" OD Casing, 4 j-rs, N-ßO, 7:J/,IIf,t Range 3 8-Rnd T & C 10%" OD Ca~;in~J, ?~1 Jt's, p_.~)¡, SIf,!/H Range 3, Buttress T & C 2.7/8" l'~_'LJt-. l'LJ",) " ne,', (;;c:-, ,J'l"S, I 1'1 "~Ii (1.u 0-':)5, 6.S!r f¡' Range 2, 8 Rnd, T & C 7" [x'tTerno Line Ca,òinq, 43 ,jis, ¡':::<rTcrne' Line, 23flft, Range 3, flush joint L i ner- E.kovJn e¡ank J-5:J, HanSJer 51 ip,; l. j ner Hanq()r· ')1/,," I ·,nc:>r' ('eCI1'·""" _, (~_ - ..;, ,).. I , 20# 1ft. Ranqe 3 Flu ,; 1'1 .J 0 i n i , Slott()d ,:;1/2" Linct-, Secur-i1'y f:lush Joint' J - ':j 5, 20,1/ fi', f\an~Y3 3 Cernen·j' 1::>lu9 í-lE:LL 12 PROF'HE South Ba.T.TO¡4 Field Naval P(~troleum Reserve No. 11 lÜaska . . 2 . 4 D R ILL I NG E QUI P MEN T LAY 0 U T Geologist Wanigan ~MUd / SD Tank Wanigan Pump Wanigan Pipe Racks T- ----- -----' \ / ~ / " Oilfield Warehouse I I .J Boiler v~anigan Water Storage Wanigan C-250 Pump & Quads .... l Cardwell Rig HOWCO Unit ------ Shop ~50/75 ~W Generator ~ Wanlgan Mess Hall Crew Change Wanigan Dry Head SCALE: 1" = 50 ft. _,~._,.,........,_ ..__ ~... >,_._...ún· .".._,.._~ ......_um...'....~~.......',""""'_,,_ -..-. __.,...._~.. ..."....,"".'0/-...... -.-., .-"....·_<_...........,,"-"",,"~..._·..~h..___...__ __.."'r'_ "....~~".. --......"'.-.-....---,.. NAVAL PETROLEUM RESERVE NO.4 SOUTH BARROW FIELD BARROW, ALASKA WELL 12 LOCATION J: 63,360 E:/.$ ON /. 4BO 04' ~.oon ~ 16 14 13 17 o Avak Test We II South Barrow lo 19 20 21 22 Well No 12 /9 21 22.8' N of S line 24 1754.9'Wof Eline Sect. 23--0 30 29 28 27 26 25 30 29 28 3/ 34 35 ~~ 36 31 !::::~ LagA ~~ T2EN T21N 3 2 I 6 32 33 32 33 6 5 4 "'I"'~'~ .,~..,¡.;..'"_.." ..,..-...j.. '" ......' '-',,", '...".....,.." ""~~"""'''''''''-'''''',,~.. ".""'...,.........."~.."'......~i;_.....";.. -." -.. '.,'.' ..........y.... ,........-_~;"',.~~ .___~,..._.Þ."."'" ..,....,'.....-' ,,_ -'''._.~.~.'' ..........~"~;.,... ._".......................,~.'."- ~"r ,-..... ~..-......,....."',....".-.........""'._."'....."'.._. -.~,",".."...",.,....~.........".~...,~.........~. '" ~.,,,,. ..". ""'-'.~. ~".,.""'.'""'" ,_..Q;': 3 5 4 IV ·e U1 t-t 0 () :Þ' t-3 H 0 Z 22 :e 27 t-d 08 MAR 74 09 MAR 74 10 MAR 74 11 MAR 74 12 MAR 74 13 MAR 74 14 MAR 74 15 MAR 74 16 MAR 74 17 MAR 74 18 MAR 74 19 MAR 74 20 MAR 74 . . 3. D R ILL I N G JOURNAL Moved equipment from South Barrow No. 11 to South Barrow No. 12. Started rigging up. Continued rigging up. Continued rigging up. Mixed CaC12 solution. Spudded at 2130 hours. Drilled 14% inch hole from 31 feet to 44 feet, with Bit No.1. Drilled 14%" hole 44 feet to 208 feet with Bit No.1. Opened hole from 14 %" to 22" with rerun PHO. Ran 4 joints (160') of 16" casing. Cemented same. Cement in place at 1000 hours. Waited on cement. Waited on cement from 0001 hours to 1600 hours. From 1600 hours to 2000 hours drilled float collars, cement and shoe. From 2000 hours to 2400 hours, drilled 14 %" hole from 208' to 315' with Bit No.1. From 0001 hours to 0200 hours, drilled 14 %" hole from 315' to 352' with Bit No.1. From 0200 tò 0400 hours, tripped for bit. From 0400 to 2400, drilled 14 %" hole from 332' to 865' with Bit No.2. From 0001 to 1030 hours, drilled 14%" hole from 865' to 1070' with Bit No.2. From 1030 to 1630, conditioned hole for logs. During 1630 to 2100, pulled out of hole. From 2100 to 2400 hours, ran Schlumberger logs. Logged from 0001 to 0400 hours. From 0400 to 1200 hours conditioned hole for casing. From 1200 to 2350 hours ran and cemented casing. From 2350 to 2400, squeezed. From 0001 to 0145 hours, squeezed cement. Had 400 PSI. Bumped plus with 1,000 PSI. Cement in place at 0200. Waited on cement from 0200 to 2400 hours. Waited on cement. Nippled up. Ran cement bond log. Changed liners in pump. Waited on cement from 0001 to 0400 hours. From 0400 to 0430 tested blowout preventers. Drilled out float collar (cement green). From 0430 to 2300 waited on cement. Drilled 9%" hole from 2300 to 2400, 1070' to 1134' with bit No.. 3. From 0001 to 2400, drilled 9'la" hole from 1134' to 1785' with bit No.3. 21 MAR 74 22 MAR 74 23 MAR 74 24 MAR 74 25 MAR 74 26 MAR 74 27 MAR 74 28 MAR 74 . . From 0001 to 0330, repaired mud lines. From 0330 to 0630, drilled 9%" hole from 1785' to 1840' with bit No.3. From 0630 to 1200, tripped for bit. 1200 to 1800 drilled 9~" hole from 1849' to 19~5' with bit No.4. From 1800 to 2000 conditioned hole to core. From 2000 to 2400 pulled out for core barrel. From 0001 to 0200, trip~ed in with 30' Christiansen core barrel and Navy owned 7 ï8" x 31/2" core head. Core barrel plugged. From 0200 to 1300, tripped to unplug core barrel. From 1300 to 1500, cut 20' core. From 1500 to 1800, pulled core No.1. Made full recovery. From 1800 to 2400, picked up Halliburton test tool. From 0001 to 0200, tripped in with drill stem test (DST). From 0200 to 1200 tested 1885' to 1985'. From 1200 to 2000, pulled DST No.1. Went in hole with core barrel from 2000 to 2230. 2230 to 2400, core No.2 from 1985' to 2017'. Pulled core No.2 from 0001 to 0300. Made full recovery. From 0300 to 0900, tripped in and conditioned hole. From 0900 to 1100 made core No.3 from 2017' to 2046'. Pulled core No. 3 from 1100 to 1400. Made full recovery. Tripped in with core barrel from 1400 to 1600. From 1600 to 1800 cored No.4 from 2046' to 2076'. From 2000 to 2400, pulled core No.4. Made full recovery. From 0001 to 0300, tripped in with core barrel. Conditioned hole from 0300 to 0700 core No.5 from 2076' to 2101'. From 0700 to 1100, pulled core No.5. Made full recovery. From 1100 to 1300 picked up test tools for DST #2. From 1300 to 1700 tripped in with DST #2. Packer failed. From 1700 to 2300, pulled test tools. Packer set at 1985'. Tripped in with DST #3. Tripped in from 0001 to 0300 with DST #3. Packer failed. From 0300 to 0900 pulled DST #3. Packer set at 1946'. Traveling blocks locked. From 0900 to 1600, changed trav- eling blocks. From 1600 to 1830, tripped in with Bit No.5. From 1830 to 2400, reamed 7 % II. hole to 9 %", from 1986' to 2077'. From 0001 to 0100, reamed 7 %" to 9 %", interval 2077' to 2101'. From 0100 to 0900, drilled and circulated for samples 2101' to 2163'. From 0900 to 1300, conditioned hole, pulled bit No.5. From 1300 to 1500, tripped in with core barrel. From 1500 to 2230 cut core No.6 from 2163' to 2192'. From 2230 to 2400, pulled core No.6. From 0001 to 0200, pulled core No.6. Made full recovery. From 0200 to 0430, tripped in with core barrel. From 0430 to 0830, cut core No.7 from 2192' to 2220'. From 0830 to 1200, pulled core No.7. Made full recovery. 29 MAR 74 30 MAR 74 31 MAR 74 01 APR 74 02 APR 74 03 APR 74 04 APR 74 05 APR 74 06 APR 74 07 APR 74 08 APR 74 09 APR 74 10 APR 74 . . From 1200 to 140Q, changed bearing in core barrel. From 1400 to 1800, tripped in with core barrel. From 1800 to 1930, cut core #8 from 2220' to 2250'. From 1930 to 2400, pulled core No.8. Made 27' recovery. From 0001 to 0300, picked up, tripped in with DST #4. From 0300 to 1200, tested interval 2100' to 2250'. From 1200 to 1400, reversed out test. From 1400 to 1800 pulled DST #4. From 1800 to 2100, tripped in with bit #5. From 0001 to 0200, reamed 7%" to 9%" interval 2217' to 2250'. Drilled 2250' to 2255'. From 0200 to 0600, conditioned hole, tripped out with Bit #5. From 0600 to 1000, tripped in with core barrel. From 1000 to 1600 cut core #9 interval 2255' to 2285'. From 1600 to 2200, pulled core #9. Made full recovery. From 2200 to 2300, laid down core barrel. From 2300 to 2400, ran Schlumberger logs. From 0001 to 1400, ran Schlumberger logs. From 1400 to 2400, laid down 7 % II drill collars. Reduced crew to one day tour of 9 men and 2 men on night watch. Performed miscellaneous maintenance. Performed miscellaneous maintenance. Performed miscellaneous maintenance. Fabricated lubricator for swab. From 1200 to 1300, ran 6" rerun bit to shoe. Circulated at 1070'. From 1300 to 1800 circulated. From 0600 to 1800, hooked up test tanks. From 0600 to 1800, tripped to bottom, cleaned out 3' fill. Conditioned hole. Tripped out. Picked up test tool; stood in derrick. From 0600 to 1800, laid down drill pipe and kelly. Changed rams in blowout preventer. From 0600 to 1200, picked up test tool and drill collars. From 1200 to 1800, picked up 2~8 EVE tubing. From 0600 to 1300, ran tubing to 1,000 feet. Circulated. From 1300 to 1800, tripped out and ran packer. Interval tested 2192' to 2288'. Swabbed from 0600 to 1600. From 1600 to 1800 ran Star Eng. testing equipment. From 0600 to 1800, Star Engineering did testing and sampling. 11 APR 74 12 APR 74 13 APR 74 14 APR 74 15 APR 74 16 APR 74 17 APR 74 18 APR 74 19 APR 74 20 APR 74 21 APR 74 22 APR 74 23 APR 74 24 APR 74 25 APR 74 26 APR 74 27 APR 74 From 060~O 1600, Star Engineering~d sampling. 1600 to 1800 pulled packer loose. From From 0600 to 0800 pulled test tools. From 0800 to 1330, tripped in to plug. From 1330 to 1600, plugged back from 2190' to 2070' with 30 sacks of Permafrost and 30 sacks of Class G. Cement in place at 1530. From 0600 to 1800, waited on cement. Tripped for bit to polish plug. From 0600 to 1800, found top of cement at 2032'. Drilled out to 2075'. Tripped out and picked up DST tools. From 0600 to 0700, tripped in and set packer. Swabbed from 0700 to 1200. From 1230 to 1330, flared well. From 1330 to 1530, shut in. From 1530 to 1600, flared well. From 0600 to 0930, flared well through Shaffer bean pressure a£ter 15 hours: shut in 895 PSI, decreased to 340 through ~~" choke in 1 hr. 15 min. Increased with %~" choke to 380 in 55 minutes. Pulled DST tools, laid down drill collars and test tools. From 0600 to 0800, loaded out test tools. From 0800 to 1200, tripped in with bit. Cleaned out to 2088'. From 1200 to 1800, circulated. Picked up 7~" drill collar. From 0600 to 1800, mixed CaC12. Displaced drilling mud. From 1600 to 1800, mixed CaC12. Circulated. Pulled tubing. Ran DST tools in hole. Packer set at 2014 DST #7. From 0600 to 0900, swabbed well in. From 0900 to 1800, flared well intermittently. Tested flow rate. From 0600 to 1400, tested. From 1400 to 1800, pulled packer loose. From 0600 to 1800, worked packer through tight hole. From 0600 to 1800, finished tripping out DST #7. Mixed CaC12. Tripped in with 9%" bit. Cleaned out fill to 1375'. From 0600 to 1800, cleaned out fill from 1760' to 2060'. From 0600 to 1200, cleaned out fill to 2075'. From 1200 to 2000, ran 48 joints (1884') of 7" 23# Range 3 casing. Cemented with 340 sacks of Permafrost and 278 sacks of Class G cement. Cemented in place at 2215. From 0600 to 1800, waited on cement. 28 APR 74 29 APR 74 30 APR 74 01 MAY 74 02 MAY 74 03 MAY 74 . . From 0600 to 1800, cut off 7" casing. Nippled up. From 0600 to 1800, finished nippling up. Cleaned out cement to 1830'. From 0600 to 1800, drilled out cement and shoe. Ran bit to 2088'. No cement below packer shoe. Pulled out to shoe. From 0600 to 1800, ran bit to 2088'. Pulled out and picked up 51/2" liner. liner at 2062'. Checked for fill. Ran in and h.nng From 0600 to 1100, ran 65 joints (2053') of 2'la EUE 8 rnd. Range 2 tubing. From 1100 to 1800, rigged down blowout preventer equipment. Rigged up to swab. From 0600 to 1200, pumped 60 barrels CaC12 solution into formation. From 1200 to 1800, swabbed well. 04 MAY 74 From 0600 to 0800, swabbed well. From 0800 to 1200, flared well. From 1200 to 1800, rigged down. 05 MAY 74 Rigged down with 6 man rig crew. 06 MAY 74 Continued to rig down. Moved equipment to Gas Well No. 5 for workover. 07 MAY 74 to Worked on Gas Well No. 5 13 MAY 74 13 MAY 74 Continued to rig down and move equipment. 14 MAY 74 Continued to rig down. 15 MAY 74 Skidded rig to South Barrow No. 13. . . 4. DRILLING CREW AS OF 27 MARCH 1974 SUPERINTENDENT TOOL PUSHERS DRILLER DERRICKMAN MOTORMAN FLOORMAN FLOORMAN ROUSTABOUT ROUSTABOUT MECHANIC OPERATOR ARDCO DRIVER Rig Area Support Crew FOREMAN OPERATOR CARPENTER OILER ~ogi8tia8 Support MECHANIC MECHANIC OPERATOR ROUSTABOUT Camp Support COOK BULLCOOK KITCHEN HELPER WAREHOUSEMAN CLERK TIMEKEEPER Bill Jacoby W. B. Barnett F. M. Roberts Morning Tour John Jacoby Johnny Maresh Vern Conway Douglas Edwardsen James Donham Joshua Nashaknik James Aiken Tom Welborn Walt Rasmussen Jerry Russell Cliff Johnson Larry Kaleak Mac Davis Lloyd Ipalook Paul Reiman Al Bales Andy Kemak John Zellar Charles Durkow Caleb Nayukok Eunice Aishanna Ken Siebert Lula Ahsoak Maynard Moline 0600 to 1800 1800 to 0600 Evening Tour Jack Crabtree Jodie Tyler Frank Parchman Walt Ahmoagak William Reagan Joe panigeo, Jr. Steve Hopson Jerry Fries Charlie Edwardsen Elmo Unrein ¡"orrr;. 9-331. C (May 1063) . UNìTED STATES DEPARTMENT OF THE INTERiOR GEOLOG ICAL SURVEY APPUCAT¡ON FOR PERMiT TO DRill, DEEPEN, OR PLUG SACK &mMIT :IN TRJ}'LICe (Other instructicns on reverse side) Fonn HIJproved. Budget Bureau No. 42-it1425. 5. LEASE DESIGNATION AND I'1ERIAL NO. Naval Petroleum Reserve #4 6. IF INDIAN, ALLOTTEE OR TRInE NAME N/A 11\. TYPE OF WORK o. TYPE OF WELL OIL 0 WELL 2. NA~IEJ OF opERA'rOR GAS WELL I[J IKJ DEEPEN 0 PLUG BAC< 0 7, UNIT AGREEMENT NAME D¡xILL OTHER SINGLE ZONE IX] :r.rULTIPLE ZONE o N/A 8. FARM OR LEASE NAME Director, Naval Petroleum and Oil Shale Reserves N/A 9. WELL NO. 3. ADDRESS OF OPERA'rOR 12 Rm. 550, Crystal Plaza 116, Washington, DC 20360* 10. FIELD AND POOl., OR WILDCAT 4. LOCATION OF W¡¡;LL (Report location clearly and in accordance with any State requirements.·) Wildcat At suri'nce Alaska State Coord. System Zone 6: 6,305,300 (N); 11. SEC.,T.,R.,l\r.,ORBLK. AND SURVEY OR ARIaA tt d695,850 (E); Umiat Prime Meridian. Approx. 71014' 16.5"N propose proü. zone , Sec t. 26, T22N, R17W same as surface) 156020 15.0"W N/A 1"2.IiõüNTY OR PARISH 113. STATE North Slope Alaska 17. NO. OF ACItES ASSIGNED TO THIS WELL N/A 14. DISTANCE IN MILES AND DIRECTION FROM NEAREST TOWN OR POST OJi'Ji'Icm. 10.6 mi Hi. DISTANCE FltO:r.¡ PROPOSED· LOCATION TO NEAREST PROPERTY OR LE,\SE LINE, FT. N/ A (Also to nearest drlg. unit JIne, !f any) 18. DISTANCE FROM PROPOSED . LOCATION· ~~ A~;~I~~S;OR~~~~T~~~J~~~<;;, ~~fPLETED, 5.9 mi 16. NO. OF ACUS IN LIIASIiI 19. PROPOSED DIiIPTH 2,350 ft 20. ROTARY OR CABLE TOOLS Rotary 21. ELEVATIONS (Show whether DF. RT. GR. etc.) Ground: Approx. 12 ft MSL: KB ~ 16 ft MSL 22. APPROX. DATE WORK WILL START. 09 MAR 74 23. PROPOSED CASING AND CEMENTING PROGRAM SIZE OF HOI,E SIZE OF CASING WEIGHT PER FOOT SETTING DEPTH QUANTITY OF CEMENT 14 3/4 in 10 3/4 in 51 lb 1. 260 ft 750 EX (theoretic::!l) 9 5/8 in 7 in 23 lb wifh 1,650 ft 436 sx (theoretical) Open hole frim approx 1,650 to 1,750 ft 5-in O.D. pe::::-f. liner. The Director, Naval Petroleum and Oil Shale Reserves intends to drill a well in Sect. 26, T22N, R17W, Umiat PM. The contractor is Pacific Architects and Engineers, Inc., Los Angeles, Calif. The well is being drilled to test the South Barrow Gas Sand in a structure about 6 mi from the presently producing structure. It will be drilled through the South Barrow Gas Sand to test deeper horizons for possible productivity. If gas is found in the South Barrow Gas Sand, but no deeper pay is found, deeper zones will be isolated by cement plugs and the well completed as shown above. If deeper production is found, a revised program will be submitted. The well is being drilled to augment the reserves of gas available to meet the needs of government facilities in the area, and the community of Barrow. *Direct inquiries to: Officer in Charge, Naval Petroleum Reserve No.4, Barrow, AK 99723 IN ABOVE SPACE DIDSCRI13E PROPOSED PROGRAM: If proposal is to deepen or plug back, give data on present productive zone and proposed new productive zone. If proposal is to drill or deepen dlrectlonaUy, give pertinent data on subsurface locations and measured and true vertical depths. Give blowout ~:~venter p~~ .. 0 ~ SIGNED R. ""V. slial~~R~ USN TITLB Officer in Charge DAT)'] 24 FEB 74 (This space for Federal or State office use) PERMIT NO. APPROVAL DATH APPROVED BY CONDITIONS OF APPROVAl" IF ANY: TITLE DAT)'] . " ,\ '. ,. '," J,: "'" OIL AND GAS CO.VArION COMMITTEE' PERMiT TO DRilL OR DEEPEN . Di\iLL [X DEEPEN 0 6. LEASE DmlGNATION AND-SERIAL NO. 'Naval Petroleum Reserve #4 '1. IF INDIAN. ALLOTTEE OR TRIBE NAME N/A la. TYPiI or WORK b. TYP¡: OJ ' WIILL OIL 0 OAS fXJ W~LL WELL ~ ~. NA"ME OF OPERATOR OTBlJa SINGLII 0 ZONI: MI'I.Tlrl.1: 0 ZON.: 8. UNIT FARM OR LEASE NAME N/A Director, Naval Petroleum and Oil Shale Reserves 3. ADDRESS C1i' OPERATOR ~~ 550, Crystal Plaza #6, Washington, DC 20360* 4. LOCATION OF WELL At surface Alaska State Coord. System, Zone 6: 6,305,300N; 695,850E; Umiat At proposed prod. zone Principal Meridian Same as surface 13. DISTANCE IN MILES AND DIRECTION FROM NEAREST TOWN OR POST OFFICE· 9. WELL NO. 12 10. FIELD AND POOL. OR WILDCAT Wildca t 11. SEC.. T.. R. M.. fBOTIOM HOLE OBJECTIVE) Sect. 26, T22N, R17W 12. 10.6 mi 14. BOND INFORMATION: TYPE N/ A N/A N/A Amount 17. NO. ACRES ASSIGNED TO THiS WELL N/A Su rety and/or No. 15. DISTANCE FROM PROPOSED· LOCATION TO NEAREST PROPERTY OR LEASE LINE. Fr. (A15o to nearest drig, unit, if any) 18. NO. OF ACRES IN LEASE· 18. :6ïSTANCE FROM PROPOSED LOCATION· TO NEAREST WELL DRILLING, COMPLETED, OR APPLIED FOR. Fr. 19. PROPOSED DEP'I'H 20. ROTARY OR CABLE TOOLS 5.9 mi 2,350 ft Rotary 21. ELEVATIONS (Show whethcr DF, RT. CR. etc.. Ground: approx. 12 ft MSL; KB ~ 16 ft MSL 22. APPROX. DATE WORK WILL START· 09 MAR 74 23. PROPOSED CASING AND CEMENTING PROGRAM SIZE OF HOLE 14 3/4 in 9 5/8 in Open hole ! SIZE OF CASINGl WEIGHT PER FOOT _ GRADE SETTING DEPTH \·10 3/4 in 1 51 lb N-80 1,260 ft 7 in 23 lb J-55 1,650 ft approx 1,650 to 1,760 ft with 5-in perf. 750 sx 436 sx liner. q uant i ty of Ceme nt (theoretical) (theoretical) rm The Director, Naval Petroleum and Oil Shale Reserves intends to drill a well in Sect. 26, T22N, RI7W, Umiat PM. The contractor is Pacific Architects and Engineers, Inc., Los Angeles, Calif. The well is being drilled to test the South Barrow Gas Sand in a structure about 6 mi from the presently producing structure. It will be drilled through the South Barrow Gas Sand. to test deeper horizons for possible productivity. If gas is found in the South Barrow Gas Sand, but no deeper pay is found, deeper zones will be iso- lated by cement plugs and the well completed as shown above. If deeper production is found, a revised program will be submitted. The well is being drilled to augment the reserves of gas available to meet the needs of government facilities in the area, and the community of Barrow. (Continued next page) IN ABOVE SPAC'I!: DESCRIBE PROPOSED PROGRAM: If proposal Is to deepen give data on present productIve zone anel proposed ""~rÕduct~Yø"Wn"I\)r_.p~!1 I. 1<1 drllt or ~pen dU"1!ctJonauy, IIlVe penmen! datA on .ubsurface IocåtlolUl and mea.......d anel true vettlc~'dciJlhs. G¡'Ie blo ,l preve~ter program. 24. I her,ìb~~-"ei\d':-lh'a¡_1;.~C ForCII~1 Ii: s True..aA~ct '"\ .....~~<.:.- (I""':" ~. R. . S1rÃ: E·, CDR, CEC, USN srGNJ:D (This space for State offlce use) DATE 24 February 1974 Officer in Charge TITLE DYES o NO CONDmONS OF APPROVAL, II" ANY: MUD LO'G OTHJI:R REQUIREMENTS: o YES 0 NO SAMPLES AND CORE CHIPS REQUUUi:D DIRECTIONAL SURVEY REQU1JŒI) o YES 0 NO A.p.r. NUMERICAL CODE PERMIT NO. APPROVALDATJ: APPROVED BV TlTLIII . ·Sø Il'Imuctionl On R.VGrac Sid. DATI: ./' ., !. . .'- .' In\· ~ ... :' ::: '.. ¡.-, ,,', .. . . STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE PERMIT TO DRILL OR DEEPEN (CONTINUED) This application is being filed for information purposes. Please see Director, Naval Petroleum and Oil Shale Reserves letter serial 394 of 27 August 1968. *Direct inquries to: Officer in Charge, Naval Petroleum Reserve No.4, Barrow, Alaska 99723 ~ /' ~ - ~, ., I. I . ¡A~? . . . . \hev. 6-6;;} DEPART~~-~FS~~kE~NTERSI:;M; IN GEOLOGICAL SURVEY WELL COMPLETION OR RECOMPLETION REPORT AND; LOG * D,UPLIC,''''.' ,(SN'ot - . st l'u('.tion~ on l'eVerse side) 1"(:on approvf.;'(.ì. Budget Bureau No. 42-R355.5. -5. ,.EASE DESIGNATION AND SERIAt. NO. Naval Petroleum Reserve #4 6. IF INDIAN, At.LOTTEm OR TRIBE NAMm N/A la. TYPE OF WELL: on. '0 (.AS [] DR V 0 WELL WJo:LI, Other b. TYPE OF COMPLETION: NEW 0 wonK 0 DFaJI'- 0 I'I,UG 0 DIFF. 0 W FJf.f, 0'· En EN BACK CESVR. Other 2. NA)IE OF OPERATOR 7. UNIT AGREEMmNT NAME N/A s. "ARM OR t.EASIC NAMII1 Director, Naval Petroleum and oil Shale Reserves 3. AnDRESS OF OPERATOR N/A 9." WICLt.' NO. Room 550, Crystal Plaza #6, Washington, D. C. 20360 4. 1.0CA·1'ION OF WEI,L (Report location clearll! and it~ accordance with anll State rçguirements)· At surfnce Alaska State Coord. system Zone 6: 6,30:>,300 (N); 695,850 (E); Umiat Prime Meridian. Approx. 7P14'16.5'tN Á t, top prod. Interval reported below 156 0 20 ' 15 . 0" W ' 12 10. FIELD AND POOL, OR, WILDCAT - South Barrow 1,1. . SEC., T., B.. M.. OR Ot.OCI< ANDSDRVEY .OR ABEA Section 26, T22N, R17W ;'., At: total depth 114. PERMI,T NO. D~TIC ISSUED 12. COUNTY OR 113. STATE 'PAOISa: . N/A ! i N/A North Slope- Alaska 1:>. DATE SI'UDDICD \16. DATE T.D. REACHED \17. DATE COMPL. (Ready to prod.) 18.EL¡¡¡!ATIONS (DF, RKB, RT, GR. ETC.)· I' 19. Et.EV. CASINGIIEAD 10 MAR 74 16 APR 74 4 MAY 74 , KB26MSL ' 20. TOTAL DEPTH, JoID &. TVD 121. PLUG, BACK T.D.. JoID &. TVD \ 22. III' Mut.TIPLm COM PL., ' '_I 2,,3. INTERVAt.S ROTARY 'l'OOLS CABLE TOOLS HOW MANY. ! ;.. ! DRILt.ED BY 2287 2088 N/A. ,', ; ~ I 2287 ft~·\ 0 24. PRODUCING INTERVAI.(S), OF THIS ÇOMI'LETION· TOP, BOTTOM, NAME (MD AND TVD).: ' . 25. WAS DIRECTIONAL SURVEY MADE South Barrow Gas Sand - Geological particulars on file with Officer in Charge 26. TYPE ELECTRIC AND OTHER LOGS RUN OIL, FOC, CNL, BGT, HOT, BHC, CBL, BROX-ML 127. Yes W AS WELL CORED Yes CASINO SIZE WEIGHT, LB./FT. CASING RECORD (Report an strings set in well) DmPTH SET (MD) HOLE-snm-~~----'-' CEMENTING RECORD AMOUNT PULLED 21\. 16" 103/1t" 7" 75# N80 51# P5l 23# 160' 1067' 1884' 22" 143;11 " 95/8" '345!SX Permafrost 0 950 SX Permafr.:>st 0 340'SX Perm., 270 SX Class "g" 0 TOP (MD) LINER RECORD BOTTOM (MD) 30. TUBING RECORD 29. 1884 o SCREIIIN (MD) slotted SIZE 27/8" DEPTH SET (MD) PACKER SIIIT (MD) SIZE 5112" SACKS CEMENT· 2062 2053 N/A 31. pli1RII'ORATION RECORD (Interval, size and numòer) 32. ACID. SHOT, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATmRIAL USED None. 33.- PRODUCTION! , (Flowlng, gal lilt"p'umping-lille and' tllPe. 01 pump) o 360* I WELL STATUS (Producing or shut-in) Shut in t:,~AS-~ICF. WATER_RRt..' I UAS-ûIL RÀTIO WATER~~L. I OIL ~;~TY'API (CORR.) I TEST," WITNESSED 'BY A.Crane:. DATil FIRST PRODUCTION I PRODUCTION METHOD Never produced DATE OF TEST HOURS TESTED CHOKE SIZE pROD'N. FOR TEST PERIOD )r OIL--BBL. OIL--BBL. 24 APR 74 FLOW. TUBING l'IIßSS. CASING PRESSURE CALCUt.ATED 24-HOUR RATIII ~ 34. DISPOSITION OF GAS (80Id, used lor luel, vented, etc.) GAS~MCI1'''' . 35. LIST OF ATTACHMENTS --->...-G/~ ~Zle~Ld-rcorrect as d~termlned fromall.av~IlRble rec~rds, SIGNED /. TIT¿~ ¡tficlr'in Charge .' DATE 2""-28-75 R.V.Shafer, LCOR.C ,USN ... (See Instructions and Spaces for Additional Data o~ Reverse Side) *Multipoint back pressure test. SUBMIT IN DUaTEO {S~~ other In- ~~~~~;~~¡d~~ 5. API NUMERICAL CODE j 01":1\ P-7 . 51 A if Of ALASKA OIL AND GAS CONSERVATION COMMITTEE COMPLETION OR RECOMPLETION REPORT AND LOG * 011. 0 WELL wonK 0 DEEp· 0 O'"F.R ES WELL la. fÝPE-·ô1'-w'ffJ:.L: GAS IV1 WELL ~ DRY 0 Oth~r b. TYPE OF COMPLETION: :"iEW 0 WgLL PLUG 0 BACK Other DIFF. 0 nESVR. 2. NUl E OF OPERATOI\ Director, Naval Petroleum and Oil Shale Reserves 3. ADDRESS OF OPERATOR Room 550, Crystal Plaza #6, Washington, D. C. 20360 4. ¡,OCATIO:< OF IV ELL· (Report location clearlu and in accordance with anll State requirement.)· At surface Alaska State Coord. System Zone 6: 6,305,300 (N) ¡ 695,850 (E)¡ Umiat Prime Meridian. Approx 71014'16.5"N At top prod.lnternl reported below 156020'15.0"W At total depth 6. LEASE DESIGNATION AND SERIAL NO. raval Petroleum Reserve #4 7. IF INDIAN, ALLOTTEE OR TRIBE NAME N/A 8. UNIT,FARM OR LEASE NAME N/A 9. WELL NO. 12 10. FIELD AND POOL, OR WILDCAT South Barrow 11. SEC., '1'.. R., M., (BO'ITOM HOLE OBJECTIVE) Section 26, T22N, R17W 12. PERMIT NO. 13. DATE SPUDDED 114. DATE T.D, REACHEDJ15' DATE COMP-SUSP OR ABAND. 116. ELEVATIONS (DF, RKB, RT, GR, é:'I'C). 17. ELEV. CASINGHEAD 10 MAR 74 16 APR 74 04 MAY 74 KB=26'MSL ,. , ~ 18. fOTAL DEPTH, MD & TVDf9. PLUG, BACK MD & TVI>r' IF MULTIPLE COMPL.. 121. J:<TERVALS DRILLED BY 2287 2088 . HOW MANY' N/A ROTARY TOOLS '2287 ft I C~LE TOOLS 22. PRODUCING INTERVAL(S). OF THIS COMPLETlOiN-TOP, BOTI'OM. NAME (MD AND TVD)' . '23. WAS DIHECTIONAL i SURVEY MADE South Barrow Gas Sand. Geological particulars on file with Officer in Char~e Yes J 24. TYPE ELECTRIC AND OTHER LOGS RUN DIL, FCD, CNL, BGT, HDT, BHC, CBL, BROX-ML 25. CASI1'rG SIZE CASING RECORD (Report all strings set in w£1l) WEIGHT, LB/FT. P GRADE I' DEPTH SET. (MD) HOLE SIZE 75# N80 160' 22" 51# P51 1067' 14 %" 23# ~8a4' 95/8" sx sx sx 16" 10314" 7" 345 950 340 20. LINER RECORD 27. SACI{S CEMENT" SCREEN (MD) SIZE o slotted, 2%" SIZE TOP (MD) BOTTOM (MD) c; lþ" 1884 2062 '28. PERFORATIONS OP1LN TO PRoDuCTlOl'i (Interv41, size and number) CE¡\1LNTING RECORD AlVXOUNT PULLED Permafrost 0 Permafrost 0 Perm., 270 sx Class "G" 0 - TUBING RECOP..D DEPTH SET OVID) 1 PACKER SET (MD) N/A ,! 2053 2Ð. ACID, SHOT, F3.ACT'üRE, CEMENT SQU!:EZE, ETC. DI;J?TII INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED Never produced '.',1 PRODUCTION '·"üDUCTION r PRODUCTION METHOD (Flowil,S, gas lift, pumping-size and type of pump) Never p;p~~ced I DATil OF TIIST, [HOURS TESTED CHœ<E SIZE IPROD'N FOR TEST ..EfUOD .?1 ~PR 74 , ~ FLOW, TUBING CASING PRESSURE CALCULATED OIL-BBL. PREss. 11 21-HOUR RATE 'I I )a 31. DISPOSITION OJ' GAS (Sold, u.ed lor jud, vented, etc.) WELL STATUS (producing or ~J1ut-ln) Shut in ··ìA.S-MCF. I W ATEIt-BBL. I GAS-OIL RATIO WATE&-BBL. lOlL GRAVITY-API (CORR.) o N/A ¡TEST WIT:<ESSli:O BY I A. Crane OIL-BBL. I o GAS-MCF. I 360* 32. LIST OF ATTACHMENTS 33. 1 hereby certify that tbe foregoing a~d a",e~ntormatlon ~ompl e and correct as determined from all available records 7-v~ ~~ Q-'=f' . Ch SIGNED TITLE J.. ~cer ~n arge DATE R.V.Shafer.r.CDR CEC.USN *CSee Instructions and Spaces for Additional Data on Reverse Side) 2-28-75 . . SOUTH BARROW TEST WELL NO. 12 ESTIMATED FORMATION THICKNESS AND DEPTHS By Clifford L. Mohr February 27, 1974 At the No. 12 location, the maps and report of the recent seismograph work indicate that the depth to the Cretaceous-Jurassic contact is approximately 1550 feet, that the Barrow gas sand immediately underlies this contact, that Upper Triassic rocks probably are present, and that the top of the argillite "basement" is near 2340 ft. The geological data from South Barrow Test Well No. 3 and Avak Test Well No. 1 suggest that the depths and presence of some members of the stratigraphic column at the No. 12 location might vary considerably, more or less as indi- cated in the following tabulation: FORMATION TOP DEPTH RANGE (ft) THICKNESS (ft) Pebble shale 890 - 1490 400 - 600 Jurassic 1550 - 1890 0 - 100 Prospective Gas Sand 1800 - 2100 0 - 90 Barrow Gas Sand 1890 - 2190 110 - 150 Lower Pliensbachian 2190 - 2340 0 - 50 Sinemurian 2040 - 2340 0 - 60 Hettangian 2100 - 2340 0 - 60 Upper Triassic 2160 - 2340· o - 180 Argillite 2340 1500+ In my opinion, the seismograph depths to the top of the Jurassic and the top of the Argillite will prove to be nearly correct; but depths to the Barrow gas sand and other intervening formations might be very questionable, owing to the presence of four or five unconformities. " . ~-) '," !~. I.' :- . It", ..' ,,,,;,' J.): s~ ;'.1 ., ," o - 208 208 211 211 - 220 220 - 230 230 - 240 240 - 250 250 - 280 280 - 370 370 - 390 390 - 440 440 - 460 460 - 480 480 - 490 490 - 540 540 - 620 620 - 630 630 - 680 680 - 690 690 - 740 .. . . SOUTH BARROW GAS WELL NO. 12 Sample Description by C. L. Mohr No samples caught. Bottom of conductor casing 159. Gray clay, traces of cement and fractured pebbles. Upper Torok formation. Gray clay and silty clay, occasional chert pebbles. Drilled rough like conglomerate. Gray clay, very good sample. Gray clay, trace of silty clay, one broken chert pebble which would appear to be residual from under the casing shoe. Gray clay and silty clay. Gray silty clay. Gray clay. Gray clay, trace os silty clay. Gray clay. Gray silty clay. Gray clay. Gray clay, trace of silty clay. Gray silty clay. Gray clay. Gray clay, several dark chert granules 2 to 3 rom diameter Gray clay. Sample lost. Gray clay. ",I.) ~I' .~. I::' ... . ."_ ../ t': j'., .... t~, 740 - 750 750 - 760 760 - 770 770- 800 800 - 820 820 - 830 830 930 930 - 940 940 - 990 990 - ·1000 1000 - 1010 1010 - 1030 1030 - 1040 1040 - 1045 1045 - 1070 1070 - 1080 1080 - 1090 1090 - 1100 1100 - 1150 ., . . Gray clay, some slightly silty clay. Gray clay, trace of siltstone. Gray clay, one dark chert pebble. Gray clay, traces of fine hard siltstone not seen above 770. Probable disconformity at 770, underlying formation Middle Torok. Gray clay and darker gray clay shale not seen above 770. Gray shale and very fine shaly siltstone. Gray clay and shale. At or near 770 there is an abrupt change from pure gray clay to distinctly darker and more indurated material having the common characteristics of a shale rather than the massive clay which occurs above this depth. The implication is that the two types of material were deposited under different environmental conditions and are separated by a disconformity. Sample mostly gray clay or silty clay like that above 770 with minor embedded cuttings of dark gray shale. Gray clay shale. Microfossils (?) 960-970, small thin shell fragments 980-990. Gray shale. Gray shale and silty shale. Gray clay shale. Gray shale, two chips of white flint from a broken pebble. Gray shale, trace of very fine siltstone, slight kick on gas detector. Cemented 103Á inch casing at After 36 hours found cement cement. 1067 ft. and soft. After 68 Gray shale. got returns. hours drilled Gray shale, a fragment of coarce round frosted sand em- bedded in a shale matrix, trace of cement. Gray shale, trace os silty micaceous shale. Slightly silty gray shale. Gray shale, moderate kick on gas detector. 2 -, >'..,,>:- ,,:.';' ~/~ r:¡t ..1. ,. I. " ,.....¡., ".. ' '-'. 1150 - 1160 1160 - 1170 1170 - 1190 1190 - 1200 1200 - 1210 1210 - 1220 1220 - 1230 1230 - 1240 1240 - 1250 1250 - 1260 1260 - 1270 1270 - 1275 1275 - 1280 1280 - 1285 1285 - 1290 1290 - 1320 1320 - 1420 1420 - 1430 1430 - 1440 1440 - 1450 1450 - 1470 1470 - 1480 1480 - 1490 1490 - 1500 .. . . Gray shale and slightly silty shale, gas kick. Gray shale, gas kick at 1175. Gray shale and slightly silty micaceous shale. Silty gray shale, one frosted quartz grain. Clayey siltstone with a few embedded fine to coarse frosted sand grains. Shaly siltstone. Upper Torok. Shaly siltstone and gray shale. Unconformity 1225. Gray silty shale. Middle Torok. Gray clay shale, trace of pyritized organic matter. Very finely silty light gray clay. Light gray silty clay and clayey siltstone. Light gray silty clay and clayey siltstone. Drilled faster 1267-1275. Circulated. Gray shale. Drilled fast 1275-1280. Circulated. Gray shale. Gray shale, some silty shale. Gray clay which balls up on bit. Dark gray clay shale. Same with abundant pyritized plant remains. Dark gray shale. Dark gray shale, a little sandy pyritic shale with occa- sional embedded coarse frosted sand grains. Dark gray pyritic shale, one broken quartz pebble. Dark gray silty shale. Dark gray pyritic shale. Dark gray shaly siltstone and shale, slight traces of medium grained sand and pyrite. 3 -' 't, ..~ : II . '",I .'. " '¡ /'f~~ I~i .~ I; J' " -. ~ . ../ " ".'-.. .,. "r' 0,' i 1500 - 1510 1510 - 1520 1520 - 1530 1530 - 1540 1540 - 1550 1545 - 1555 1555 - 1560 1560 - 1570 1570 - 1580 1580 - 1590 1590 - 1600 1600 - 1610 1610 - 1620 1620 - 1630 1630 - 1640 1640 - 1650 1650 - 1660 1660 - 1670 1670 - 1680 . . Very dark gray silty shale, trace of very fine rounded sand probably reworked from the Jurassic. Very dark gray silty to sandy shale, trace of to very fine angular to rounded loose sand. Dark gray slightly shale. Samples are poor because of having shale from 1300 to 1500 feet. Dark gray finely sandy to silty shale, occasional coarse quartz grains. Dark gray silty shale and shaly siltstone, trace of fine hard sand. Grab sample from shaker screen. shale. Show of gas Ì545-l557 on Cl "'20,000 PPM C2 1,400 PPM C3 280 PPM C4 SOO PPM Slightly silty dark gray gas detector: Very fine shaly sand and dark gray shale. Fine shaly snad with occasional medium to coarse frosted grains, much silty shale, trace of pyrite. Dark gray silty shale, much fine shaly sand. Silty, shaly sand and very fine shaly sand. Very fine shaly sand and silty shale. Dark gray slightly silty shale, some fine tight shaly sand. Dark gray shale. Very fine hard silty sand, trace of dark gray shale, a few granules of quartz and chert. Fine tight shaly sand with occasional dark chert granules, some silty shale. Fine hard shaly silty sand. Dark gray shale, a little siltstone. Dark gray silty pyritic shale and very fine shaly sand, trace of frosted granules like those int the "Pebble Shale." Fine hard sandy siltstone, some very fine free sand and 4 ;-- !. 11",,1, \ J ','. " ,..\I:"~ ' .."f· f; ..:.\: ,1 1680 - 1690 1690 - 1700 1700 - 1710 1710 - 1720 1720 - 1730 1730 - 1740 1740 - 1760 1760 - 1770 1770 - 1780 1780 - 1790 1790 - 1800 1800 - 1810 1810 - 1820 1820 - 1830 1830 - 1840 " . . silt, a few dark chert pebbles as in the "Pebble Shale." The shale and siltstone resemble the Middle Torok. Dark gray shale and silty shale. Very fine shaly tight siltstone, some very fine porous sand with a few quartz and chert granules. Fine silty sand with a few medium-size grai?s, a few quartz and chert granules, much silty shale. Very fine shaly siltstone and grayish black shale, trace of medium grained rounded sand. Some of this material closely resembles the "Pebble Shale." Above 1710 the sands and siltstones more closely resemble the Middle Torok. Probable unconformity and top of Middle Torok near 1715. Possibly this unconformity occurs as high as 1640. Gray-black shale with occasional embedded coarse sand grains. "Pebble Shale." Grayish black shale, sandy shale, and shaly sand with fine to medium-size grains and abundant large frosted quartz grains typical of the "Pebble Shale." Grayish black pyritic shale, fine to medium-grained sand with abundant dark chert granules. Grayish black shale with numerous embedded dark chert and frosted sand granules. Very good sample. Black shale with broken chert pebbles, trace of hard sand. Dark gray silty shale (all cavings from Middle Torok). Shut down to clean plugged flow line. Badly contaminated sample. Some grayish black shale with dark chert granules. Mostly cavings(?). Grayish black shale with quartz and chert granules. Light gray finely silty shale and very fine siltstone unlike the "Pebble Shale" but more closely resembling the Jurassic. Unconformity and top of Jurassic 1810. Light gray silty shale and shaly siltstone with occasinal quartz and chert granules from above. Light gray silty clay and clayey siltstone. 5 -, ·-',I.'r .'- .... .,. ..\{',,\. ~,/ ::;..'t~ '.. ... ¡'., 'f', 1840 - 1845 1845 1845 - 1850 1850 - 1860 1860 -1870 1870 - 1880 1880 - 1900 1900 - 1910 1910 - 1920 1920 - 1930 1930 - 1940 1940 - 1950 1950 - 1960 1960 - 1965 1965 - 1985 . . Sample lost on trip at 1845. Circulated to clean hole and remove trip gas. Very fine shaly silty sand, a little free porous sand, trace of pyrite and coarse quartz grains. Small showing of gas near 1847. Very fine subangular to subround sand and siltstone, part of which appears to be porous. At least half of sample appears to have considerable clay matrix. Lithology is typical of upper part of South Barrow gas sand. Very fine, very argillaceous siltstone. Gray flaky shale and silty shale. Very fine argillaceous sand, some gray shale. Very fine argillaceous sand, considerable loose sand. V~ry fine argillaceous to very argillaceous sand. Very fine subangular to subround sand, some clean porous sand. Very fine argillaceous sand, some clusters of porous sand, a little free sand. Very fine argillaceous sand, more clusters of porous sand, more free sand. Very fine argillaceous sand, increase in porous sand, faster drilling 1955-1965. Circulated 30 minutes. Slightly argillaceous to clean loose sand. Core No.1. Recovered 20 feet. Cores have good odor of gas. Lithologic details: 1965 Very fine subangular to subround quartz intimately associated with very fine quartz siltstone, no apparent clay matrix. Dip about 5 degrees. 1967 Like preceding. 1969 Like preceding. 1971 Fine subround to subangular quartz sand with many dark chert grains, no apparant clay matrix. Dip 6 . _~.J \','> .'. '.. ., ,".:," ....., ~" . . 3 degrees. 1973 Fine sand like preceding but with less silty matrix porosity. 1974 Similar to preceding. 1976 Very fine hard siltstone without indications of porosity. 1977 Fine to very fine subangular sand somewhat porous but with matrix of silt. Dip about 4 degrees. 1979 Fine to very fine subround to subangular sand with extremely silty matrix. Dip about 4 degrees. 1981 Very fine frosted silty sand, no bedding planes. 1983 Fine subround frosted snad, less matrix silt and better porosity than proceding. '1985 Very fine sand to very fine quartz silt, poor porosity. 1985 - 1986 Reamed. 1986 - 2016 Core No.2, recovered 30 feet. 1986 Siltstone, slight clay matrix. 1987 Very fine subangular sand, finely silty matrix 9 minutes per foot. 1989 Fine subangular sand, very slight matrix. 2 MPF. 1991 Very fine subangular sand, very slight matrix 3 MPF. 1993 Fine sand, many black grains, slight silty matrix 2 MPF. 1995 Fine subangular to subround sand, coarser and cleaner than preceding. 1 MPF. 1997 Fine sand like preceding but with more matrix. 2 MPF. 1999 Fine to very fine sand, silty matrix. 2 MPF. 2001 Like preceding. 2 MPF. 2003 Very fine sanå1, bedding planes of fine silt. 2005 Fine subangular to subround relatively clean 7 '" . " '1'" \ - ",' ·E!,~ :I/.'_::}: .' '-"'" ,'.: ',. < .;.~ . · . sand, dip 5 degrees. 2 MPF. 2007 Very fine silty sand, many black grains, 2 MPF. 2009 Very fine silty sand with slight clay matrix and trace of pyrite. 7 MPF. 2011 Like preceding. 3 MPF. 2015 - 2016 2013 Very fine silty sand. 5 MPF. 2015 Very fine silty sand. 5 MPF. Drilled, no sample. Core No. 3. Recovered 30 feet. 2016 - 2046 2016 Fine silty sand, low porosity. 5 MPF. 2018 Very fine sand with very finely silty matrix, faint configuration on bedding planes resembling plant remains. 4 MPF. 2020 Fine subround frosted sand with very silty matrix. 3 MPF. 2022 Very fine sand with very silty matrix, plant remains. 4 MPF. 2024 Like preceding. 3 MPF. 2026 Hard shaly siltstone, impermeable, dip 5 degrees. 7 MPF. 2028 Very fine subround sand, rather silty matrix, well preserved pelecypod. 3 MPF. 2030 Fine frosted sand with many dark grains, moderate silty matrix, trace of soft green glouconite, 3 MPF. 2032 Medium-fine frosted sand with very little silty matrix, no bedding. Well preserved pelecypod andgasteropod at 2033. 1 MPF. 2034 Medium-grained frosted porous sand with very slight matrix material. 1 MPF. 2036 Medium-fine frosted sand with many black grains and slight matrix material. 1 MPF. 2038 Medium-grained subround frosted clean porous sand 8 --- .t e.. . . with many dark hard grains resembling the argillite basement, trace of soft green glouconite, dip 7 (?) degrees. 3 MPF. 2040 Like preceding. 2 MPF. 2042 Medium-grained frosted clean porous sand. 1 MPF. 2046 Medium-fine frosted sand, apparently quite porous but with distinct silty matrix. 4 MPF. 2048 Medium-grained subangular to subround frosted porous sand with matrix of very fine silt, trace of glauconite. 1 MPF. 2050 Like 2048, 1 MPF. 2052 Medium-fine porous sand with faint oil or gas stain and silty matrix. 2 MPF. 2054 Medium-fine porous sand, silty matrix. Unconfor- mity 2054. Base of Barrow gas sand 2054. 3 MPF. 2056 Fine tight sand with very silty matrix. This probably is the Simemurian. 7 MPF. 2058 Very fine dark silty sand with silty and clayey matrix. The general aspect of this material seems to contrast sharply with that above 2054. 6 MPF. 2060 Gray-black very fine silty argillaceous sand with pelecypods and pyritized plant remains. There are no distinct bedding planes, and dips cannot be measured. 8 MPF. 2062 Fine subangular to subround silty and slightly argillaceous pyritic sand. 7 MPF. 2064 Black argillaceous siltstone with pyritized plant remains, pelecypods and ammonites. 5 MPF. 2066 Very fine silty subangular dark gray sand, apparent- ly impervious. 6 MPF. 2068 Very fine subangular to subround silty sand with matrix of very fine silt, apparently impervious. 4 MPF. 2070 Like preceding. 2072 Like preceding. 9 -,' II"-'.,',I! :. ,. ~J"r-~t; 2076 - 2101 2101 - 2110 2110 - 2120 2120 - 2129 . . 2074 Black shaly impervious siltstone. 7 MPF. 2076 Dark gray shaly impervious siltstone. 8 MPF. Core No. 5 2077 Very fine subangular to subround sand, finely silty matrix. 5 MPF. 2079 Gray-black slightly shaly siltstone, dip about 5 degrees. 5 MPF. 2081 Dark gray shaly sitlstone, pyritized plant remains. 7,MPF. 2083 Gray-black shaly siltstone, ammonite. 9 MPF. 2085 Gray-black shaly siltstone. 6 MPF. 2087 Gray-black shaly pyritic siltstone. 4 MPF. 2089 Gray-black shaly siltstone. 5 MPF. 2091 Like preceding. 12 MPF. 2093 Like preceding. 10 MPF. 2095 Like preceding. 8 MPF. 2097 Very fine frosted silty sand. 5 MPF. 2099 Gray-black siltstone. Dip appears to be near 4 degrees. 6 MPF. 2101 Gray-black shaly siltstone. 5 MPF. Drilled very rough 2103-2110. Circulated 20 minutes. Medium to fine-grained sand with very hard quartzitic streaks and limy matrix, trace of siderite, gas show on detector, no odor upon heating. Drilled rough in spots. Circulated 25 minutes. Fine to very fine hard slightly tiny sand with a few quartz granules, some loose angular to rounded frost sand, traces of quartz granules and pebbles of light greenish-gray shale, trace of brown vuggy dolomite or siderite. Circulated 15 minutes. Mostly siltstone, some fine sand, occasional quartz granules, trace of dark gray shale. The sand is lithologically almost identical with the known Jurassic Pliensbachian sand above. Nothing distinctive of the Triassic is yet recognized. 10 . .'~ I" \ .; . '~,' ! ." . " ., ',. "',,,", 2129 - 2131 2129 - 2135 2135 - 2138 2138 - 2140 2140 - 2145 2145 - 2150 2150 - 2155 2155 - 2163 2163 - 2192 2163 - 2167 . . Grab sample. Very slight showing of oil and gas on wet sample. Three small gas shows on gas detector. No odor recognized on heated sample. Fine subangular loose porous sand; rare granules of dense lime, white oolitic lime, chert, and quartz. No visible oil stain. Similar to prceding, no visible oil stain or gas odor from heated sample. Fine hard limy and shaly sand and siltstone, a little dark gray shale, trace of broken chert pebbles. Pro- bable unconformity and possible top of Upper Triossic Shublik formation 2137. Gray shale, much fine hard limy Sðñ~, a few chert pebbles from conglomerate above 2137. Contrasts sharply with material above 2137. Gray shale, some fine silty sand. Sandy silty and limy shale with a faint greenish cast, so~e limy siltstone, pelecypod. Finely conglomesotic limy shaly sand, much gray limy shale with abundant microfossil casts, trace of hard brown to buff lime, rare chert pebbles and coarse sand grains. Gray shale and shaly fine to coarse sand with granules and pebbles of brown and black chert, white oolitic lime and quartz. It is not clear at this point in the drilling whether there is an unconformity near 2163 representing the base of the Jurassic and top of the Triassic with the interval from 2137 to 2163 a thin Jurassic remnant such as the Hethangian or whether the conglomerate be- tween 2137 and 2163 belongs with the congomerate above 2163. Core No.6. Recovered 25 feet. No recovery. 2167 Started coring slower at 2164. Very shaly black siltstone. Unconformity near 2164. 14 MPF. Top of Triasssic 2164. 2168 Black shale. 12 MPF. 2169 Black silty shale. 11 MPF. 2170 Black silty shale. 11 MPF. 11 It""I:!' .. , . ¡:/ .' .. , .<¡.. , . . 2171 Black silty shale. 11 MPF. 2172 Black silty shale with pyritized plant remains. 12 MPF. 2173 Black shaly siltstone. Doubtful dip 7 degrees. 12 MPF. 2174 Black shaly siltstone. Dip 5 degrees. 12 MPF. 2176 Very silty blackshale. 17 MPF. 2177 Black shale. 13 MPF. 2178 Very shaly black siltstone. 15 MPF. 2179 Very silty black shale. 15 MPF. 2180 Black shale. 15 MPF. 2181 Black shale. 15 MPF. 2182 Black shale. 11 MPF. 2183 Black shale. 10 MPF. 2184 Black shale. 14 MPF. 2185 Black shale. 14 MPF. 2186 Black shale and light gray subangular limy clayey sand. 12 MPF. 2187 Light gray limy clay with medium-grained sub- angular sand. 15 MPF. 2188 Black shale. 13 MPF. 2189 Black shale. 14 MPF. 2192 - 2222 2190 Black shale. 15 MPF. 2191 Black shale. 15 MPF. 2192 Black shale. 15 MPF. Core No. 7. Recovered 28 feet. 2193 Black shale. 20 MPF. 2194 Black shale. 19 MPF. 12 " ,t".~ 1.' :. . ., f ~~' ~ j " ~,.~: ': '. , " .f .,.. , . . 2195 Black shale. 14 MPF. 2196 Black shale. 14 MPF. 2197 Black shale, plant remains. 15 MPF. 2198 Black shale, slightly silty with pyritized plant remains. 11 MPF. 2199 Black shale. 14 MPF. 2200 Hard brown shale. 14 MPF. 2201 Hard brown silty shale. 12 MPF. 2202 Hard brown fossiliferous sandy lime. 10 MPF. 2203 Brown limy oil-stained fine to coarse sand with a few quartz granules. The oil in dark brown and low gravity. 8 MPF. 2204 Medium-fine soft porous oil-saturated subangular sand. 4 MPF. 2205 Fine porous oil-saturated sand. 2 MPF. 2206 Fine to very fine silty oil-saturated sand. 3 MPF. 2207 Very fine silty oil-saturated sand. 5 MPF. 2208 Like preceding. 6 MPF. 2209 Hard fine siltstone with clay matrix, impermeable, dip about 3 degrees. 7 MPF. 2210 Like preceding. 5 MPF. 2211 Fine angular to subangular oil-saturated sand with abundant green glauconite. 4 MPF. 2212 Fine silty oil-saturated sand with more glauconite than preceding. 3 MPF. 2213 Fine oil-saturated glauconitic sand. 2 MPF. 2214 Like preceding with marine fossils. 4 MPF. 2215 Fine subangular oil-saturated sand. 2216 Like preceding. 3 MPF. 13 ;-- '._J ,\ '" , I , I, -'Of' . . 2217 Very glauconitic fine silty oil-stained sand. 2 MPF. 2218 Eíne glauconitic oil-saturated sand. 2 MPF. 2219 Like preceding. 2 MPF. 2220 Like preceding. 2 MPF. 2220 - 2250 Core No.8. Recovered 30 feet. 2222 Mostly fine sand, many quartz granules, much glauconite, very fossiliferous. 1 MPF. 2223 Very glauconitic fine angular sand with silty matrix, oil-saturated. 1 MPF. 2224 Like preceding. 1 MPF. 2225 Lide preceding, extremely glauconitic. 1 MPF. 2226 Like preceding. 1 MPF. 2227 Like preceding. 1 MPF. 2228 Like preceding. 1 MPF. 2229 Fine to coarse, very glauconitic, fossiliferous sand. Oil-saturated. 1 MPF. 2230 Fine to coarse sand with granules of quartz and green shale, much glauconite, oil-saturated. 1 MPF. 2231 Fine oil-saturated sand. ']here are no bedding planes that indicate the dip. 2 MPF. 2232 Like preceding. 4 MPF. 2233 Fine silty hard light oil-saturated sand. 2 MPF. 2234 Fine oil-saturated sand. 4 MPF. 2235 Like preceding. 2 MPF. 2236 Very silty fine hard oil-saturated sand. 2 MPF. 2237 Like preceding. 4 MPF. 2238 Fine hard tight silty oil-saturated sand, dip near 3 degrees. 2 MPF. 14 ., ,11,.\ .ij, , ',' -, :/ '.' ¡.. . . 2239 Like preceding. 2 MPF. 2240 Like preceding. 2 MPF. 2241 Fine oil-saturated sand. 3 MPF. 2242 Fine oil-saturated silty sand. 2 MPF. 2243 Like preceding without fossils. 3 MPF . 2244 Like preceding without fossils. 3 MPF. 2245 Like preceding. 2 MPF. 2246 Like preceding. 3 MPF. 2247 Like preceding. 2 MPF. 2248 Fine hard silty fossiliferous sand. 2 MPF. 2249 Like preceding. 2 MPF. '2250 Like preceding. 3 MPF. Drillstem test 2096 to 2250; 950 ft. mud and some oil in drill pipe. 2250 - 2255 Drilled. Medium to fine grained hard angular sand and miscellaneous cavings. 2255 - 2285 Core No.9. Recovered 30 feet. 2255 Fine angular oil-saturated sand with abundant glauconite and shell fragments. 2256 Fine hard silty poorly oil-saturated tight sand. 6 MPF. 2257 Fine hard silty oil-saturated sand, very tight, fossil fragments. 4 MPF. 2258 Like preceding. 3 MPF. 2259 Very silty fine hard poorly saturated sand, fossil fragments. 3 MPF. 2260 Like preceding. 2 MPF. 2261 Like preceding. 2 MPF. 2262 Very finely sandy siltstone with a white clay matrix, few fossil fragments, no porosity. 3 MPF. 2263 Fine silty sand with greenish gray silty clay 15 " ~I' '~.,. \ I > ;(..,:\{ J~~~ 1"', '" ,. ;.. . . pebbles from weathered basement, much glauconite fossil fragments, moderate oil saturation. 3 MPF. 2264 Sand as above and argillite as below, 4 MPF. Base of Triassic and top of argillite. 2265 Light gray indurated laminated talk-like argillite. Light color is result of weathering. Dip 18 degrees. 2265 Very hard gray-black argillite. Dip 20 degrees. 2266 Like preceding. 2267 Like preceding, dip 20 degrees. 2268 Very hard, very miceceous argillite, dip 20 degrees. 2269 Like preceding, dip 32 degrees(?). 2270 Like preceding, dip 25 degrees. 2271 Like preceding, a vein filling hades. 2 degrees. 2272 Like preceding with secondary quartz. 2273 Gray-black argillite. 2274 Same, dip 21 degrees. 2275 Same, dip 16 degrees. 2276 Same, dip indefinite. 2278 Same, dip 20 degrees. 2280 Same, dip 25 degrees. 2282 Same. 2283 Same, total depth. -~;;LÄ ç ((ø¡F-J .~, ~ <L ' 16 -/ ~ ;'å~~~? // /\. ,. t., 'J \,... ì. 'I ,t,1 II " ' ·..~i '. ;- " ,. 1965-1979.0 1979-1979.7 . . Core log South Barrow 12 4" core, nearly complete, in 2 3.5 ft lengths per box. Packed in plastic bags. I. L. Tailleur, C. Mayfield, 1/7/75. Megafossils identified by R. W. Imlay, 1/29/75. VF ss/sls, It olive gray with darker streaks from bioturbidation; character varies little; subangular to angular glassy qz; point-packed and compacted by clay filling pores. Binoc: 1970.0 - VF, clear, ang-subangular glassy qz, minor glauco non-calc. 1978.8 - VF-F as above. Sls, med gray, carbon. flakes and rods... 2 cm. Binoc: 1979.4 - sls/VF, clay-packed, <5% black grains; non-calc; mod. perm. 1979.7-1981.5 F. ss, olive gray friable, muddy, <1'. Grades down to cleaner, F glauconitic ss. 1981.5-1997.4 VF ss/si1tstone, clayey; grades fro~ above; sl. harder 1983-85; bioturbid, wasting etches sl. wavy, v. thin dark laminae, annnonites: coroni- ceras? @ 1987.4; paracoroniceras. @ 1987.5, 1987.6. Binocs: 1982.8 - Clayey sls as 1979.4 1987.8 - VF, clayey, <1% glauco (Ammonites) 1997.4-2022 VF sandstone, silty, med olive gray; s1. varia- tion in prominence of dark (bioturbid) films, fewer @ 2008-2011, more films and argillaceous layers @ 2018. Carbonized wood with FeOx halo @ 2000.1. Pelecypod Lima? @ 2010.3 and shell frags @ 2015.5 and 2018-2022. SP and DIL con- tinue low profiles begun @ 1965. Binoc: 2000.1 - VF-F, ~5% dark grains, <1% glauco 2010.3 - VF, clayey. >1% glauco (Molluscs) 2018 - < 2 cm mudstone layer, dk gray, with VF sandy laminae; <5% dark grains. 2022-2032 VF-F ss, sl. friable, lower 3 ft slightly coarser and lacks bioturbid features, structure. Struc- ture1ess except for shell frags. 0.5' silty clay layer @ 2026. Fossil frags and clusters locally: 2029.2; 2029.3-wood, Eopecten (=Velo- pecten) @ 2030.8. Binoc: 2026 - Mud shale, v. sandy, dk gray. 2029.2 - VF-F; mod. clayey; <5% glauc and black grains, ~l% translucent iron-stained grains. (clams) û> 2032-2034 2034-2045 2045-2046 2046-2054 2054-2055.5 2055.5-2076 . . 2030.8 - VF-F; grain-supported, pores rimmed and filled with clay; M calc. grains, 5 cm concretion, mass/dense, dark gray. (clams) F ss, becomes almost punky, oil-soaked? Lump of Fe cemented conc at 1033. F-M ss, poorly indurated, porous, wet/oil- stained? Slight variation in grain size. 2-5 cm zone of densely cemented rock @ 2036. Prob- ably correlates with increasing resistivity @ 2034. Binoc: 2044.2 - F-M, sub-ang to ang. glassy qz.; <5% each glauconite, porce1ainite?, and dark grains; most porous of above sa.p1es. Dense sandy rock--probably siliceous, concre- tionary? E-10g kicks diminish about 2046. Eopecten? Binoc: 2045.8 - Sls, dk gray, with M. calc. grains (molluscs, wood.) Ss, F-M, friable, wet, non-bioturbid. Binoc: 2052.7 - F, 1t. olive gray, subangular-subround glassy qz, <5% each dark grains and glauc. Abund. pores filled with clay. Sls, VF-F, wet; mass of hard, dense, concre- tionary?, material. Ss, VF, silty, argillaceous" bioturbidated; silt or clay slightly variable up to half. Thin chitinous and greenish sulfidic flakes to rods. Minor concretionary material near top; scattered wood fragments Arnioceras, Sulci- ferites?, Otapiria, Eopecten, crinoid column @ 2056', Otapiria tailleuri Imlay @ 2051', 2058', 2064.2; Otapiria and Charmasseiceras @ 2061.5' and 2068'. Binoc: 2056' - Sls, sandy/VF 55, little clay apparent; numerous white, pitted earthy grains; com- pact. Pelecypods. 2057' - Ss, VF, moderate admixed clay, weakly friable; dark streaks from bioturbidation. 2064' - 55, VF, compact, bioturbidated: small, light-colored lumps and dark streaks and laminae (indistinct under microscopic); "1,,1% F. glauco (~ 2076-2101. 0 2167-2169.5 2169.5-:-2176' 2176-2178.5 2178-2198.5 . . Sls,/VF ss, as above; slightly more argillaceous overall, bioturbidated, thin dark- and light- colored laminae in part. Numerous greenish pyrite flakes, horizontal worm tubes; med gray. Otapiria @ 2078.5'; Monotid pelecypod @ 2083.7'. Binoc: 2078.5' - VF ss as 2064' above 2088' - VF ss as above; with <1/4" streaks and broken thin layers of compact silty mud. 2101 - VF ss (slightly coarser than above); clay pore filling; streaks of dark-colored material from bioturbidation. Core No. 6 Clay shale/claystone, dark brownish gray, scattered carbon/chitinous grains; non-strati- fied but sha1y parting. 3" dense concretion. Binoc: 2167' - VF ss, silty claystone; clay rises to surface on wetting. Silty clay shale/claystone, thinly stratified; Fragment Psiloceras (Franziceras??) @ 2170.5'. Binoc: 2169.8' - Clay shale, med to med-dark gray, thinly fissile, irridescent pyrite in small films and grains. Fissile surfaces show minute slickensides? 2170.5 - Sls, VF sandy, arg., streaks of cl.y; mostly dark gray with lighter-colored streaks; carbon grains 2175.5 - Sls as above; flattened fretwork of darker-colored streaks. Clayshale w/~-5" med. brownish gray concretions, some flattened, oblate. Sl. oxidized pyrite on branches? twigs, lines. Binoc: 2176.7 - Sls, clayey, VF sandy; <~" lumps of dark gray aphanitic clay. Porous to HCl and exude clay. Clay shale/claystone, dark brownish gray to grayish black. Numerous small concretions. 6" clot of rounded concretionary fragments @ 2187', some F. sandy matrix, 6" softer shale at 2190'. Partly thinly laminated and grada- tional thin layers of medium greenish gray clay. Streaks, imprints of dark brownish gray pyrite. Fragment of Waehneroceras?? @ 2181.5'. Binoc: 2180' - Dark gray, very finely, fissile clay shale with horizontal layer, 1-1.5 em, of ~ 2198.5-2201 2201-2201.3 2201.3-2202 . . olive-brmroish gray, dense non-calc material. 2184' - Dark gray, clay sÌlale as above, scat- tered carbonaceous/flakes (sample for organic analysis). 2187' - 1 cm layer, clayshale as above; 2-3 cm layer argillaceous sls/silty claystone. Unoriented thin fragments -> 2 cm of clay- stone. 2189' - V. thinly laminated clayshale as above. Slightly irregular thin layers etched on washing. 1 em lump of pyrite. 2192.3 - V. thinly, flaky, parted clay shale as above. No carbonaceous flakes noted. (Sample for organic analysis). 2198' - Clay shale as above. Lumps or clots up to 1 cm of VF ss/sls, scattered thin laminae of VF sand and oblate, dark to brownish concretions, 2~ by 6 em. At top, 4" grayish black clay shale with It orange (rusty), slightly rounded fragments greater than 1" across of silty concretions. l' subangular fragments (breccia?) interlensed in mud; most have weathered, earthy texture. Grayish black clay shale at bottom. Binoc: 2200 - 5 cm of massive sls, argillaceous in part; with clasts -'5 cm of ironstone, and weathered labile material, c. glassy quartz, scattered carbonaceous grains 2 cm a.t base of clay shale as above; fine fabric resem- bling slickensides on parting surfaces. 2200.6 - clay shale as above, dark gray, silty. Scattered carbonaceous grains, pyritized films or spines and small, white, non-calc. rods. Medium gray, dense compact claystone, scattered sand grains. Appears bentonitic but kaolin and i11i.te on X-ray, as similar bentonitic-looking shale @ 2550' in South Barrow No.3. VF or aphanitic, yellow orange matrix to float- ing angular fragments and chips of dark green- ish gray porcelainite. Binoc: 2201.5 - Upper 3 cm of iron-stained claystone, v. thin stratification; fragments of soft glauc., scattered silt and sand grains. Lower 1-2 cm of dense to silty material, iron-stained glauc., chips of earthy, It greenish gray, non-calc rock. GJ . . 2202-2204.5 F, somewhat porous, fragmental, ferruginous calc. rock; very glauconitic locally. Abund. white shell fragments: 2201.3-2204.5 transi- tion interval. Binoc: 2202.5 - F, dirty, iron-stained, clay pore- filled glauconitic clastic rock. Abund. shell clasts. Compares to iron-stained rock at top logged Triassic in Barrow 3. 2204.5-2208 Ss, VF, friable, oil-stained. Possibly bio- turbidate lower part. Binoc: 2207.5 - VF ss, same as below, scattered VF glauc., decided brownish gray color. 2208-2210.5 Ss, VF to sls, dense matrix. Binoc: 2209.5 - VF/s1s, subround glassy qz grains (25%); slighter smaller limonitic colored grains (>5%); F-M black grains; rare mus- covite. Seems dirty in that pores between closely packed grains filled with clay. Non-calc; medium to medium light gray. Clay did not exude on washing. Rock feels harder, more compact than 2202.5. 2210.5-2212.5 Ss, VF-F, argillaceous, bioturbid; v. glauco in part. Some white shell frags. Oil-stained. 2212.5-2229 Ss, F-VF, friable, variable glauco Oi1- stained. 6" siltier more calc @ 2228.5. Abundant shell fragments (undet.), less stain, 2222-24' . Binoc: 2214 - VF-F as above, dark yellowish brown, no limonite-stained grains, a few percent glauc.; scattered black, resistate grains. 2222.8 - Ss, F-VF, silty, glauc, M shell clasts, dark yellowish brown (oil stain) 2229-2230.5 Ss, F, M. glauc, C, shell fragments limonitic or oil-stain. Binoc: 2230 - M-C carbonate (shell) and VF qz sand. Mod oil-stain. 1-2 em thick dense, gray, mud layer, rvlOo. 2230.5-2250 Ss, F-VF, glauc local; shell sand. lower. Oil-stain varies from almost saturated to moderate with grain size and less silt. Binoc: 2231. 3' - F-VF ss, mod. friable, v. strong oil stain (£) 2255-2263 2263-2263.5 2264 . . 2238.5' - VF close packed ss., dark bioturbid? streaks, strong oil stain. 2247.8' - M. carbonate (shell) sand as @ 2230 above except rare glauco Sand VF/sls, bioturbid, med. olive gray to mod yellowish brown, several tight calcareous zones like Shublik from Prudhoe wells. Glauc. local- ly indeterminate pelecypods and gastropods. Binoc: 2256.5' - Sls/VF ss mod olive gray, F. shell grains. Indistinct dark streaks. 2258.5' - sls/VF ss as above; bioturbid 2259.5' - VF ss, silty, mod. yellowish brown; F. white grains. Snail 2261.5 - VF ss/sls as above. 2262.5 - VF ss/sls as above. Ss, F, oil-stained. Laminae and thin layers of clay and mud at base, shell fragments. Binoc: 2263.5 - VF silty ss, mod yellowish brown. Argillite, grayish black, laminae thin graded beds dark gray sls. @ ~-~' '..-- 11T,Wl'Ir'uI.N'l' BACK P.SURE TEST9 GAS lrJELT. ,NO,,12, S" .ROI'¡ GAS FIELD NO,,2 Gas .AnaJ.ys:i.s - C1'i tj.cal Data Methane Ethane Propane Ni troge...''1 HeliUJll Argon Hydrogen Specific Gravi~ Gross BTrJ / cu. f't . Critical Gas Tern.D oR .1:_-. " ~._ Methane .923 x 343.5 = 317.05 Ethane .008 x 550 = 4.4 Propane .001 x 664 = .664 Nitrogen .048 x 227 = 10.896 H e1i um .0197 x 10 = ..197 - Psuedo-critical temperatUl~e: 333.2oR. Bottom Hole Pressure - Weigh~ of Colunù~ of Gas 92.3 % 0.8 % 0.1 % 4.8 % 1.97 % Trace Tra ce 0.571 952 Cr-1 tical Gas Pres sure He'lihane .923 :x: 673 = 621.179 Ethane .008 :x: 717 = 5 73" . 0 Propane .001 x 617 = .617 Nitrogen .048 x 492 = 23.616 Helium .0197 x 33 = .65 Psuedo-critical pressure: 651.798 psia .- " """'" I "D P., GL "'s = .J.. e .!:>'J .)4~1'm I + P b 1 + P1b s - ':- - where Ps .,. bottom hole pressure, psia PI = wellhead pressure, psia G = specific gravity of gas (air = 1) 1 = depth of well, feet Tm = average tempe rature of gas column, oR. Tm = Ts - Tl In Ts - Tl Ts'" temperature at bottom of well, oR. T1 co tempe rature at wellhead, oR. In'" natural logarithm e b = Naperian logarithm base = 2.718 = deviation coefficient = ..1..- P1Z¡ 1 - P1 where PI = wellhead pressure, psj.a = supercompressibility factor at wellhead pressure9 average temperature of gas column. ; Page 2 . . Bottom Hole Pressure - ~~ight of Column of Gas, Continued p = '"1 G = Ts :: T1 = L == Tm 810 psig + 15 = 825 psia .571 51BoR (based on temp. bomb test Well No.2) 475°R 2,063' :: 518 - 475 In (518) (f?B) 43 In (1.0905) ... 43 .0866 == 497 oR. = 1:) = psuedo-reduced pressure "'1" Tr = psuedo-reduced temperature P ... 825/651.8 == 102657 1" Tl" ... 497/333.2 == 1.4916 21 ... .875 (Tables for P r ' Tr) b = 1 PI Zl - .0013852 - .0012121 == .0001731 1 P:L == 1 825 x .875 1 825 p s ~ ,-- - 0.571 x 2063 2.718 ,).34 x 497 == 825 1 + (825 x 0.000173) - .- - ~ ~ 825 80.044435 2.71 . 1.142725 == 721.958 x .044435 log 2.718 1 -I- PsO.000173 - = - - - = 721.958 (1.0453) == 754.66 Ps = 754.66 (1 + .000173~s)== 754.66 + 0.13056 Ps .86944 Ps ... 754.66 Ps == 868 Bottom Hole Pressure = 868 psia wt of Colu~~of Gas == 868 - 825 == 43 psi ~~:·¡L:,G2. . Conditions Shut-in Wellhead Pressure: Bottom Hole Pressure: Weight of Column of Gas: Barometric Pressure: Base Pressure: Base Temperature: Psuedo-critical Temperature: Psuedo-critical Pressure: Specific Gravity: Formula Flow M:!ïe: Q ... (Fp) (Ftf) (Fg) (Fpv) (Pm) . 810 psig 868 ps:ta 43 psi 15 psia 14.65 psi a 60°F. 333°R. 652 psia .571 where Q = Flow rate (at 1.l.+.65 psia, 60°F.), MCFD (thousand cu/rt/day) Fp =: Basic o~fice factor (at 14.65 psia, 60°F., and 1.00 specific gravity) Ft.:r'" FlmV'ing temperature factor'" (520 divided by flowing gas temp. °R.)~ F g .,. Specific gravity factor'" (1 divided by f'lm-dng gas specific gravi ty)~ Fpv = Supercompressibility factor'" (1 divided by compressibility factor)t ... (1 divided by Z)fâ Pm ... Static pressure on critical flm.¡ prover" psia. p2_p2 f s == Differences of squares of form.ation pressure, P f, and pressurea.t the sand face, P s . Test 1 - 3/3211 Orifice Stabilization Pressure; (615 + IS) = 630 psia Drill Stem Pressure: (612 + 15) = 627 psia Flmving pas Temperature: +35 Deg. F. F == .1446 P Ftf == 1.0249 Fg = 1.3234 Pr ... 630/652 = .9663 Tr ... 495/333 = 1.4865 z ... .901 Fpv = 1.054 Pm ... 630 .. ¡ ,'". 4 . -. ---""-'- Test 1 - Continued Q' = (.1446) (1..0249) (1.3234) (1.054) (630) D 130~2 MCFD p2 J::: (825 + 43)2= 753,424 f p2 == (627 + 43)2= 448,900 s "D2 p2 III 304!1524 ~f - s rest 2 - 1/8n Orifice Stabilization Pressure: (510 + 15) = 525 psia. Drill Stem Pressure: (510 +15) = 525 psia Flowing Gas Temperature: +37 Deg. F. F = .2716 P Ftf = 1.0229 F = 1.3234 g p ... 525/652 = .8052 r m = 497/333 = 1.4925 lr Z = .918 F == 1.044 pv p = 525 m Q ... (.2716) (1.0229) (1.3234) (1.044) (525) = 201.5 MCFD pZ p2; (825 + 43)2 - (525 + 43)2 III 430,800 f - s -= ~est 3 - 3/1611 Orifice (320 + 15) = 335 psia Stabilization Pressure: Drill Stem Pressure: (315 + 15) ... 330 psia Flowing Gas Tempe rature +36 Deg. F. F ... .6237 P Ftf &: 1.0239 Fg = 1.3234 Fr = 335/652 ... .5138 Tr ... 496/333 &: 1.4895 z CD .946 ,.:'c; :J _.- . . Test 3 - Continued FpV = Pm 1.028 == 335 Q == (.6237) (1.0239) (1.3234) (1.028) (335) == 291.1 MCFD " Pf2_ps2 a (825+43)2 - (315+15+43)2 =614.1295 Test 4 - l/l¡iI Orlf}.ce, stabilization Pressure: Drill Stem Pressure: Flowing Çias Temperature: (200 + 15) == 215 psia (195 + 15) == 210 psia +36 Deg. F. F a 10115 p Ftf == 1.0239 F == 1.3234 g Pr == 215/652 = 032975 1" 1 ... 496/333 ... 1.4895· ... r Z = .961+ Fpv = 1.0185 P = 215 m Q III (10115) (1.0239) (1.3234) (1.0185) (215) = 330,2 MCliD Pr2 - ps2 ... (825 + 43)~ - (195+ 15 + 43)2 == 689.Ll5 ;onclusion Calculated absolute open flow potential: 360+ MCFD. See results on attached logarithmio paper. ~7' ", -ft'- '," 'c> ~c'£-Á o-/a~d-e And.rew F. Crane Foreman, Nat. Gas Operations PAE · . Sotd:;h Barrow Gas l11[e11 No. 12, S. Barrow Gas Field No.2, Back Pressure Test Field Test Data Test Date: 21 April 1974 Shut-in Pressure: 810 psig Time Sta,rted: 1315 hours Tes'~ 1 - 3/32" Orifice Time 1315 1320 1325 1330 1335 1340 -; .,! I"'" .L.;J......:;¡ 1350 1355 1405 1415 1420 Test 2 1423 1435 1h40 1445 lS·00 1510 1520 1535 Drill stem Press... psig Tested by: A. Crane Ambient Temp: -10°F. Knots 14.9 psia Wind: W 8 Barometric: Metel" Pressure, psig Gas Temp.. of. F1o't-lir;g . ----------------------------------~----~-735----~--~-----+29.5 -----------------------------------------735-------------+28 -----------------------7-25---------------730-------------+32 -----------------------------------------690-------------+38 -----------------------------------------665-------------+36 -----------------------------------------640-------------+35 -----------------------------------------625~------------+34 -------~~---~--------~-------------~----~612-------------+3h --------~------------~------------------_615-------------+36 -----------------------------------------615-------------+36 ~---------~------------612---------------615----~--------+35 - 1/8 n OrLfic e. Flowing ---------------------------------------- ---------------------------------------- -----------------------------------~---- ~~-------------------------------------- -~-------------------------------------- ---------------------------------------- '['est 3 - 3/1611 Orifice -~---------------------510------------~- ....'5 l:>L~ 1600 1605 1615 1635 F101-1ing ------------~--------------------------- ~----------------------------------~---- ---------------------------------------- --------~-----~--------31'-------------- Test 4 - 1/4" Orifice 1638 1645 1655 1705 1715 1725 Flowing ---------------------------------------- -----~---------------------------------- ---------------------------------------- ---------------------------------------- -----------------------195-------------- 560-------------+35 550-------------+3h.5 535-------------+34.5 520-------------+36 515-------------+38 510-------------+38 510-------------+37 355-------------j3Q:5 335-------------+37 320-------------+36 320-------------+36 240-------------+36 205-------------+3$.5 200-------------+36 200-------------+36 200-------------+36 IU',.I'(;: L.UGARITHMIC 4b .I;j;¿U Ir'\\"~£; 2 x 3 CYCLES MADE IN U. $. A. KEUFFEL Be ESSER CO. '> -. !,a§..~ Multipoint Back Pressure Test - Gas vIel1 No. 12, S. Barr'oT¡! #2 Date: 21 April 1974 }____ __2 __ 3 j Y 6. 7 L~ ~ ? 3 4 5 _6 7 8 9 1 2 _ 3 1 5 6 7 8 ~ ~ 1 -=~;'=~~=-=~ê~J~l#~.~t.~@}J1IJ~~:Fêf-t#F~¡Jf:E-2W~t=$=.=-. -+-rr~î~~-Ff!tTtt}§i'§L1TIÈ~i. ~~ª,,-j=-Jf..¥p;lThèj~if· Wi .--~ -t::~:~~€§:::J~ê-m;:t393=ttS1~~-F}f~Er.-:¿~t:±.3fJ~KIŒITlœI[ 9.__._______.------,.--.-.,- --·--"T ---gj~'r-~,- -~= -'r---I--c-·ù~ --·--=m·=~~ -~-r.:----'-r'- --'-··-···~mt++--·- ~.,.--'-~- ---~~.c----+--C---T=.g~~-.-+-h+.. .-, ........ i"" . r, . 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I' I", I I , I ,I, "Iii" "I,,,, ,," i," -i""" ' I I ,I, I I "II--+++--~----¡-t-t---!---, " ,,, ",IlrI::J:1L! -:--t-¡ :;: I : : ¡ : ~::-tt jU ~¡ iI-¡tt¡. ttttJ:H ¡Iii i I I Iii I II '¡--rM:- tt+i- 1M-II ·1 I: i i +++-H-W-+ ~'t¡ +m-: I I -.111ri:j::l:t ~tPI-H+t--W-1- -W-~ M ":. - .. itf-j :-njl ¡ I II i i!! :â#tmr-~I¡! '.: II f ~III¡I !.';I:li !il!!' II 1 III i'll! ¡:IIII" il!, ill' l,rrijìW1. '~II ¡Ii' i _I-II' liT/1m¡':!','. ¡i¡iil !i' ill' Ii ~I' ::111' ~~_.~ì=.:.~..~.i Cï+~~~0f':nJ11 ~~~~!!!j! li!1 )Jt:!l!!~~! i¡¡1ili~~~J~M, Ii !i,!!,i!lLl,t-~~:mtJF -=-4-r--'--: I ;:' l:fT~- ;,iTfFf1:--+'!d1tJì#f\4 II Iii 111::1 ::: ::lli-;;I, ::III!I:i~i! --tt--f--+-+t-Ht:±-lfH=-mf+4ffffi-ffift \J =-=~ III Ii 11\--mtI'I-"t1T1tilluill~+w-~ I' I III II-W-ii iiii ill! Ilttit-¡ill±lliili¡ I I ¡¡_+H-I-WI'-H-i-i+-+++t--W+~##~J:±jtJt. ~ : I ! ¡: " I : I : ~; ! ~ I ! II: ~-n: lip1tn it]! I I I: I' ¡--! ~: ~ ~: II : ~,tt!TtÎGW·¡:il i I I --nr 1) )+-+++c--t-+-1-+-nrr I! rrTF=tH+--¡'~- ~ :t-t i I III ¡ !_L)lMj} ¡ II ¡ 'mJIit¡'¡ m; I III1I Iii': i i i! _: i! Ill' ¡ii' ¡ i ¡ i m-*I !I¡ii I I I ¡-=--=t+t:-:J±ttttH I ! II Ii ¡ i! I ¡ I~II : It".;:.. I ~I I I --tffl :! I I I I I ¡ + I I 'I II 1 i I ¡: , -++t+ ! I I I I ¡ i I II! I ¡ I I d I I ----m- +-++ )! ¡ I \ I, ! . +H i I I I ¡ I I It I I ~~2 1\: 11; I Ii II: i i I~¡¡-~.,: ! ill· ! !1'I~lrr.:~1~hl¡ 1~1111 Iliiij1r~,: iiITI,~i:" ,il~,¡i I ¡I -nrr,ir¡1 w.c¡!:,H¡!iPt¡ ïl~~I: I I ++hl' I I I ~-thH it !11i I -% _ I II I I --+rtt--U, II ¡ -L, ~j:jl L,~~IW~t:,-~I--=i,---,~·~ ¡'III ··~I -J ' I¡'III ~t=1 .. n~~:fm~~1 111-1111 IITlll il! III11I I m II! ---1-1111[1 2 34567891 2 34567891 2 34567891 Q :: 360+ MCFD . . Tetra Tech, Inc. Navy NPR-4 South Barrow No. 12 Well Page Two intensities of the diffraction scan with those obtained using standard mix- tures. The results of the mineral content determinations by x-ray dif- fraction are presented in tabular form on Page 3. Quartz was the pre- donrinant mineral in each sample. Clay-type minerals (kaolinite and illite) were present in each well core sample in quantities ranging from 2 to 4 per cent of the total sample. One core plug, from a depth interval of 2226 feet, was selected for the liquid permeability as a function of volume throughput determinations. The air permeability and porosity were determined on the core plug iden- tified as Sample 3. The core plug was then evacuated and saturated with a brine containing 100,000 ppm sodium chloride plus 30,000 ppm calcium. chloride. Liquid permeability as a function of volume throughput was de- termined on the brine-saturated core plug. Liquid permeabilities were also determined as a function of vo1um.e throughput using a brine containing 100,000 ppm sodium. chloride followed by distilled water. An examination of the test results indicate that the core plug exhibited moderate sensitivity to the sodium chloride brine containing calcium. chloride. No additional sensi- tivity was noted when the sample was contacted with the 100,000 ppm sodium chloride brine; however, a marked sensitivity was exhibited to the distilled water. It was a pleasure working with Tetra Tech, Inc., on this study. In the event that we can be of further assistance or should you have any questions per- taining to these test results, please do not hesitate to contact us. Very truly yours, Core Laboratories, Inc. D~f Duane L. Archer, Manager Special Core Analysis DLA:JWW:dr 10 cc. - Addressee ;þ! [ill 1 ~~~J.......__lTfI!.J!'MIØ~m-~~J.Jra::..,'n ~ . Company Tetra Tech, Inc. Number of Wells One Field Sample Number Company CORE LABORATORIES, INC. Petroleum Reservoir EngÏ1zeerÏ1zg DALLAS. TEXAS Fonnation County State Identification of Samples . Page File 1 of 4 SCAL-76385 Northern Alaska Well 1 United States Navy NPR-4 South Barrow No. 12 2 3 4 5 Depth, Feet 2206 2216 2226 2236.5 2248.5 . . CORE LABORATORIES, INC. Petroleum Reservoir Engineering DALLAS. TEXAS Page 2 of 4 File SCAL-76385 Lithological Description Sample Number Description 1 58, brn, fn-v/m grn, calc, mod indurated, frac 2 58, brn, vIm grn, vI 511 calc, mod indurated, frac 3 58, brn, fn grn, calc, mod indurated, w/c1auc, foss frag Ss, brn, fu-v/fn grn, well indurated 58, brn, fu-v/fn grn, v I calc, well indurated, fos s frag 4 5 í . . CORE LABORATORIES, INC. Pet,ol",m Res4rooi, Engine"';"g DALLAS. TEXAS Page File 3 of 4 SCAL-76385 Mineral Content Determination (by x-ray diffraction) Sample Depth, Feet: 2206 2216 2226 2236.5 2248. 5. Mineral Per Cent of Total Sample Quartz 88 55 49 72 63 Calcite 2 4 27 8 Kaolinite 2 4 2 3 3 illite 2 1 Siderite 6 33 16 19 22 Pyrite 2 4 4 6 3 Th_ .nab,_. "Phaioaa or intel-pr«.atioM are based ora otNie.....Uona and _t.eri.1 auppllecf by the clleat to whom. .ad for WhOM exclllal". aad confidential -. :!ua report Ja made. The Interpret&tiona or opinions expreued np....nt the beat jud¡cm..nt of Core Laboratories. lac. (.11 erro.. aad omi..ioM ueotpted): but ~re L..a~~to!!~. Inc. _ ud I~. office... .n~ _pl~ ~ DO. f'!!'Ipoaaiblll~y aac! .ma~e. ao warranty or rep......ntaUon. u to the', .' Y' . " . . - · . ÇOK~ L.A.t50f(ATOKI~' INC. .. P,tf'ol",m R'JØf'flo;, Engin,,,mg DALLAS. TEXAS Page File. 4 of 4 SCAL-76385 Liquid Permeability Data Sample Number: 3 Porosity, Per Cent: 25.1 Air Permeability, Md.: 283 Liquid Throughput, Liquid/Air Permeability, Md. Pore Volumes Permeability Ratio 100, 000 PPM Sodium Chloride plus 30, 000 PPM Calcium. Chloride 135 3.0 0.477 138 6.0 0.488 136 10.0 0.481 138 15.9 0.488 139 20.6 0.491 134 134 140 136 137 100, 000 PPM Sodium Chloride 4.7 10.3 17.2 24.6 32.9 0.473 0.473 o. 495 0.481 0.484 42 19 15 12 11 29 Distilled Water 2.5 6.6 12.1 18.6 22.1 (Reverse Flow) 0.148 0.067 0.053 o. 042 0.039 0.102 Th_ &lULly_. opinion. or inte''Pretation. are baaed 011 obMrvatlone and material .upplled by the eJlent to whom. arid for wh_ _cluive and confidential uee. thCoI. report I. made. The Intel"p...tatiolUl or opinion. expretl8ed ....prøent the beet judKment of Core wboratori... Inc. (all erTOn alld _i..IOM excepted); but , re wborato.riea, Inc. and Ita office... and employee&, __ no ree_lblllty and make no warrantJ" or repruentatioD& .. to the productivity, proper opera- ~ -. ,-.' -"-) ~ ~ .. "1 ~ '11-. - -"'\,. ,- ., 'i~' ..'" ,.... ." ...JI . .. . . 1,·( f '" IJ '" '. ¡ ;;;' --, --,~_!'::':'!, ~.(:\ F,: º \~ à V'~ èc ¡ ~q;~. :.:'-' t 1;\ i: ;'" '\' -~' (". HELIUM OPERATIO~Si)'S h.! \). 'ý., Rt~MIi~ed States Department of the Interior " 1 !,\ BUREAU OF MINES Q ('< BOX H 4372 HERRING PLAZA ~ AMARILLO. TEXAS 79101 ,~, ~ '.J.; \<.11. :;<-e \'" .¿ '4; April 30, 1974 Branch of Helium Resources AIRMAIL Lt. Cdr. Richard V. Shafer, CEC Officer-In-Charge Petroleum 4 Naval Petroleum and Oil Shale Reserves Department of the Navy Point Barrow, Alaska 99723 h .I-~, C; J.:.r -. V ~, :u fJ!\'{ 1: "1~·74 ", 1, .L ;j- !T I' "Fi-;THè.ü, i\U-1:::Kå Dear Sir: Enclosed are two copies of a report on the analysis of a gas sample tak~n from Gas Well No. 12 in the South Barrow Gas Field No.2. Please Note: The sample from the above mentioned well contained 3.74 percent helium, which is unusually high for gas in Alaska. Therefore, we would appreciate another sample from the Jurassic gas zone in this well to confirm the enclosed analysis. We have taken the liberty to forward another sampling kit to Mr. Crane to replace one to be used for this additional sample. Also, we would appreciate any additional information on the well and surrounding area that might be available. Specifically, we would like to have information on estimated structure, core analyses, drill stem test, well logs, and other well completion data. The Bureau of Mines Helium Operatio~s at Amarillo, Texas,provides a current file on analyses of natural gases, which is open to public inspection. In addition, the analyses \are published periodically in Bureau of Mines information circulars and bulletins. We would like to obtain permission to utilize the enclosed data for the foregoing purposes along with similar data released by other operators. It will be appreciated if you will sign the "Permission for Release" on one copy of the report and return it to us. A preaddressed envelope, which requires no postage, is enclosed. If you desire permission to publish or circulate the analytical results, please contact us. We wish to thank you for your cooperation in furnishing us with samples of gas for analysis. Sincerely yours·, Richard D.. Miller, Acting Chief Section of Helium Resources Surveys Enclosures cc: Mr. Andrew F. Crane. Foreman, Natural Gas Operations Pacific Architects and Engineering, Point Barrow, Alaska 99723 Inc. . Rt::POR i OF ANAL YSi . ,:·t,:.......... F. S. -. ·13980 M.S. ST, TE- :ALASKA , FIELD- BARROW 51 NO. 2 .;....;. ",,,.. ~. .~.....;~~. '..-.~..!'.~, ., 4 ····.·r·- ::, . '. ,~, : N-59844,H 3.£4 OBS. PRES. 67.3 CAL. PRES. 65.8 COUNTY- NOT ¡GJiVEN WELL NAME- B AR RO W S.ìN o. 12 LOCA TION- SEC. 23. ~24N. R17~ OWNER- U.S. NAVY DA TE COMPLETED-\ OST DATE SAMPLED- 04/21/74 SAMPLED BY- ANDREW F., CRANE NAME OF PRODUCING FORMATlON- .JURA- DEPTH IN FEET- Z087 THICKNESS IN FEET- 73 '·500 SHUT IN WELLHEAD PRES., PSIG- 810 OPEN FLOW, MCF/D- CHECK OF DA T A- THE WELL DATA ARE ACCURATE, ( ) WITHOUT CORRECTION, (_) AS CORRECTED ABOVE. REMARKS- ANAL YSIS- METHANE ;87.3 % NORMAL PENTANE TRACE % OXYGEN a.a % ETHANE 0.4 % ISOPENTANE 0.1 % ARGON 'TRACE % PROPANE \ 0.1 % CYCLOPENT ANE ,TR,ACE % HYDROGEN 'TRACE % NORMAL BUTANE 0.1 % HEXANES PLUS 0.1 % . H2S 0.0 % ISOBUTANE . 0.1 % NITROGEN 7.9 % CO2 0.2 % SPECIFIC GRA V r O.581.f HELIUM 3.14 % TOTAL 100.0 % CALCULATED GROSS BTU/CU. FT., DRY AT 60 DEG. F AND 30 IN. MERCURY- 910. * DUE TO THE A8S0 RPTION OF H2S DURING SAMP:t ING,jTHE,REP ORrED RESULTS r·1,\V ,NOT BE RELIABLE. PERMISSION FOR RELEASE: Permission is hereby granted for the Bureau of Mines to release the above data, together with similar data released by other operators CIS public informCltion Clnd as pClrtS of a series of papers on analyses of gClses from vClrious fields, stCltes, or regions. COMPANY BY .L TITLE UnIted ~tate~epartment at the Intena. BuREAU OF MINES ' BOX H 4372 HERRING PLAZA AMARILLO. TEXAS 79101 Nay 28, 1974 Branch of Helium Resources [UM . OPERATIONS ..' ',{' "\.. '.. D .i.t L. . -.1 j1... ;) Lt. Cdr. Richard V. Shafer, CEC Officer In Charge Petroleum 4 Naval Petroleum and Oil Shale Reserves Department of the Navy Point Barrow, Alaska 99723 MAY 3:1. í974 ¡"¡AV.t:'~'.i.Rßb, ALASKA " Dear Sir: Enclosed are copies of reports on the analyses of gas samples that were analyzed as part of the Bureau of Mines survey for helium-bearing natural gases. The samples were obtained from your Barrow South No. 12 Well. The Bureau of Mines Helium Operations at Amarillo, Texas, provides a '. currel1t file on analyses of natural gases, which is open to public --inspection. In addition, the analyses are published periodically in Bureau of Mines information circulars and bulletins. We would like to obtain permission to utilize the enclosed data for the fore- going purposes along with similar data released by other operators. It will be appreci~ted if you will sign the "Permission for Release" on one copy of the report and return it to us. A preaddressed envelope, which requires no postage, is enclosed. If you desire permission to publish or ci~culate the analytical results, please contact us. To be sure that the well data are accurate, please check the data on the report of analysis and indicate in the appropriate space whether they are accurate without correction or as corrected on the sheet. If the data sheet is not complete, ,please supply the missing iriformation. We wish to thank you for your cooperation in furnishing us ~ith samples of gas for analysis. Sincerely yours, £?(}L /:J.y: 02~-&A_<-- B. J. Moore, Chief Section of Helium Resources Surveys Enclosures. ---~ ",,_r _--... . " '-', ~, . 'oJ ....\..\ . ,v-.. . '.'\í"'p J.\. \ -_._----~ , . FŒPORT OF ANAl'{S;_ ,- 035. PRES. .C; l.õ .. b ~.' CAt. P'ŒS. - r 0.... F. S. - 1 it I: 23 M.S. N-SG133 7 ¡..¡ I. öS STAïE- _"\ L.~ $k\ A COUNTY- N C;": TH S LC ¡::::.: ¡; Of< ':U G:~ F!2lD- :.~ A;" ,,'~J ~.; S WEll NAME- 8 A!~ ';:0 t·; s: 1\0.. 12 lOCA TION- S¿Co 2~? T22N1 R17~ OWNER- U.. S.. Nr.. \l Y DA 12 COMPlETED- . C5/11/7q DATE SAlv\?lED- ·p6/13/74. SM".?LED BY- Ç~~N~t .;"1IC:·iELETTI· NAf;\E Of PRODUCING ·FORMATION- ~U~H-5~RROW SA~a DEPTH IN FEET- ~ ?-c:& 'J THiCKNESS IN FEET-· 9sf . ; SHUT IN WEllHEAD PRES., PSIG- j'/D -.~ OPEN flOW, MCFjD- - -ß7C _ ':;:> jj.- ç.1'7 -:>¿;;ó riel-£,¿; .. CHtC< OF DA T A- T;if: V-IHI.. DATA ARE ACCURATE, ( ) WITHOUT CORRECTION, ( ) AS CORRECTËD ABOVE. ~EN\AR;{S- , , > A~'lA~ YS¡s- M=r:-iAö":E c-... -, % .;;J£..J éïHANE . D...a % P~O?ANE 0.1" % NO~MAL BUTANE D..G % IS03UTANE - . C..G % SPECIFIC GRAV , C..572 .....-. : NORMAL P~NT AN:: ·0 .. G: % OXYGEN ~ :". ... ...Io..t' ISO?ENiANE f"'" :"'I u........ % ARGON ;i' :~;:I.:: ,-. CYClO?ENTANE . C..G % HYD~OGEN tT~A Cë: HEXANES PLUS f. r'!: .... ;..;...... % '*- H2S- .~ c.. c NITROGEN - 4..8 % C02 " G.G - HWUM , C7 .......,.J.. TOTAL lGC..C CALCULATED G~OS5 8TU/CU. FT., DRY AT 60 D::G. F AND 30 IN. MERCURY- 952..· ~.; '~. ;.:..- T i) 1.:1~:: t.J s.a ~~~:; T! C :·~:O f :-f2S :~ ~:::; ~..;~ 'IS . ~'\ À Y . :'-l~)T .~3 ¿ f~E" L ¡ ASL::: -0 DURI~T1G S~·~~.:~?-L I;·~G'J T w=- . . «.""- R 8' CRTE D PE!Vf.:SS·:ON fOR RELEASE: } . ?crmission is hereby granted for the Bureau OT Mines to release the c~ove data, ·tagether with similar data rer~se¿ by ú~¡"¡¡r operators os public information al1d as parts of 0 series of papers on analyses or gases from various f¡aids, states, or regions. COMPANY BY -'- TITLE .....,;... ~ F. S. - 13935· M.S.¡ N-S9. ,H: 3.59 OBS. PRES. 68. , CAl.. PRES. ,67... 5 STATÊ- . ',AU, SK A COUNTY- 11 OT ;G ¡VEt, FIELD- BARROW s: NO.. 2 WELL NAME- B AR RO W Si NO. 1 2 lOCA TION- SEC. 23. T2QN, R17W OWNER-· U.. s.· N A V Y DATE COMPlETED- 'NO T 61 VEN DATE SAMPlED- ¡ NO T 6I VE N SAMPLED BY- A.F. CRANE NAME OF PRODUCING FORMA TION- : .JUR,~- DEPTH IN FEET- NOT GIVEN THICKNESS IN FEET- NOT GIVEN SHUT IN WELLHEAD PRES., PSIG- 300 OPEN flOW, MCfjD- N or ¡GIVEN CHECK OF DA T A- THE WElL DATA ARE ACCURATE, ( ) WITHOUT CORRECTION, ( , ) AS CORRECTED ABOVE. REMARKS- ANALYSIS- METHANE ;87.8 % NORMAL PENTANE TR A CC: % OXYGEN 0.0 % ETHANE .\ .0.·4 % ISOPENTANE 0.1 % ARGON ,TRACE % PROPANE ¡TRA C£ . % CYCLOPENT ANE TRACE % HYDROGEN , 0.0 % NORMAL BUTANE . ·0.1 % HEXANES PLUS TRACE % * H2S . 0.0 % ISO BUT ANE ! T RA CE % NITROGEN , 1.1· % CO2 ' 0.1 % SPECIFIÇ GRAV 0.577. HELIUM 3..69 01 .... .."""'." I 00 0 % .""'.",. CALCULATED GROSS BTU/CU. FT., DRY AT 60 DEG. F AND 30 IN. MERCURY- 904. DUE Tn THE AßSORPTIONO'¡: H2S' DURING SAHPLING, THE JREP CRT.ED RESULTS HAY NOT BE RELIABLE. PERMISSION FOR RelEASE: Permission is hereby granted for the Bureau of Mines to release the above data, together with similar data released by other operators as public information and as parts of a series of papers on analyses of gases from various fields, states, or regions. ' COMPANY R ,':. Slr1,;FER r,G.DR. .' C]:C. USN BY Qtf··· . ~! . t II.er In '.:..i""~;£ìO ~~Çf'.'e; r¡c:F:_)1:"~i).,:1, ;·-~.c~~:-..rve r~~¡~~):?. Ba¡i"()vlf, J\i~~ ~ii./",~j 1. TITLE F. S. - 139 SG· M.S. j N_59.C:~ U3::4 hl~f:LB~~::ES. 61t CAl. PRES. 65.8 STAn;- ,;i¡ LA SK A COUNTY- NOT î6 11/ EN FIElD- BARROW S. NO. 2 WELL NAME- BAR RO W S. .N O. 12 LOCATION- SEC. 23. T24N, RI1W OWNER- U.S.. N AV Y DATE COMPLETED- OST DATE SAMPLED- 04/21/74 ¡ h J'~ C .'~; J V 12. D SAMPLED BY- .4NDR EW F., CRANE: NAME OF PRODUCING FORMATION- ..JURA- fM'!'{. I).: "9~/'4 01 1 t) .~. I . DEPTH IN FEET- Zû87 THICKNESS IN FEET- 13 NJ.\Vi'L1RES, J~Li~SKl\ SHUT IN WEllHEAD PRES., PSIG- .81C OPEN FLOW, MCF/D- '500 CHECK OF DA T A- THE WELL DATA ARE ACCURATE, ( ) WITHOUT CORRECTION, ( ) AS CORRECTED ABOVE. REMARKS- ANAL YSIS- METHANE .81.3 % NORMAL PENTANE TR ACE % OXYGEN 0.0 % ETHANE . 0.4 %. ISOPENTANE , 0.1 % ARGON TRACE % PROPANE , 0.1 % CYCLOPENTANE TRACE 0/0 HYDROGEN TRACE: 0/0 NORMAL BUTANE , 0.1 % HEXANES PLUS 0.1 0/0 * H2S 0.0 0/0 ISOBUTANE . 0.1 % NITROGEN 7.9 0/0 CO2 . ·0.2 % SPECIFIC GRAV > 0..584 HELIUM 3.74 % TOTAL l....'"' " ", uueu IV CALCULATED GROSS BTU/CU. FT., DRY AT 60 DEG. F AND 30 IN. MERCURY- 91D. DüE TO THE A6S0RPTI-ON Of H2S DURING SAMPLING.. -THE ,Rtp ORTEO RESULTS MAYNOr BE RELIAELE. PERMISSION FOR RELEASE: Permission is hereby granted for the Bureau of Mines to release the above data, together with similar data released by other operators as public information and as parts of a series of papers on analyses of gases from various fields, states, or regions. OH!Œr ïn (I¡..my;, COMPANY;"~.:~,,..j; P\.~~"I~l~\.:,~. ;:~..t<;'i-_"'" :¿.: ',.' PI [;ftrrr'v;.-, l\~< ..-.'..;'.~ .:, BY TITlE ~ñ: ·V-..·fJU~~ i ~12.:ä1 mIlo.:lJ USi L F. S. - It.tG03. ST  TE- /':- 1i ~'i«' A ..., Lf""\~'\'" FIELD- 3ÄhROt.¡ S N-S. ,H 2.53 M.S. OBS. PRES. 64. CAL. PRES. 63.'3 COUNTY- Nor :GIV£N WELL NAME- BARROW $I NO.. 1'2 LOCATION- SEC. 23, T24N, R17W OWNER- U.S. NAVY DATE COMPLETED- 1J5/0'U74 DATE SAMPLED- ; D5/05/74 SAMPLED BY- D. B AR NE T T NAME OF PRODUCING FORMATlON- J UR A- DEPTH IN FEET- 2087 THICKNESS IN FEET- 73 SHUT IN WEllHEAD PRES., PSIG- 810 OPEN flOW, MCFjD- '500 CHECK OF DATA- THE WELL DATA ARE ACCURATE, ( ) WITHOUT CORRECTION, ( ) AS CORRECTED ABOVE. REMARKS- '-- ANALYSIS- METHANE SO.6 % NORMAL PENTANE TR ACE % OXYGEN 0.0 % ETHANE , 0.7 % ISOPENT ANE 0.1 % ARGON TRACE % PROPANE T r~JI. CE % CYCLOPENTANE TR ACE % HYDROGEN 0.0 % NORMAL BUTANE 0.1 % HEXANES PLUS TR ACE % * H2S o .r. ISOBUTANE- 'TRA CE % NITROGEN 5.6 % CO2 0.3 % SPECIFIÇ GRA V 0.577 HELIUM 2.6 (i 0...( 00 T""·..· 1110.Q % ''''''''r"'_ CALCULATED GROSS BTUjCU. FT., DRY AT 60 DEG. F AND 30 IN. MERCURY- ( 933. DUE TJ THE AESOP-PiION OF H2S DURING SANPLING, ,THE REPORTED RESULTS MAY NOT BE RELIABLE. PERMISSION FOR RELEASE: . Permission is hereby granted for the Bureau of Mines to release the above data, together with similar data released by other operators as public information and as ports of a series of papers on analyses of gases from various fields, states, or regions. . ('H;;;nr in CharC'!a COMPANYl'I.,". ,.,.1 f....:-; -.- ~ I..... , ,>t........L..::d ..·~,'~":\-{¡{'tJ~ ~-,\_i:....;\ t'an\~\IŸ, Ai( t.,1 ";'L~ BY TITlE R. V.· SHf),FER LGDRu CEC, U8K L CL - 690 .ORE LABORATORIES. I.. PRELIMINARY CORE ANALYSIS RECEIVED uL COMJOANY tl. ~. NAllY; 'H. nAT'" ~'1/7"¡ WK'" 501-(.7'" ßARRow _fjPt.L:J 1¡I~t¿ft~.Q~ '"ß"n.lleu COUNTY Al9ttA. CORE. -:D 1!t·.......AI.. , C..~CI. DiP.N.4VPFTRFS DRILLING FLUID ,Jß ~ (//¡\S~~. !:.r OIL TOTAL &:t\.»ÑC. OIL US II, DE P TN PERllEA81LIn POROSITY WATER P.IØ'II.J.l.t.t IEC Ii - V '" '" ru Ou % '" , FEET II1LllDARCYS % PORE PORE ~. _u... YOLo YOLo FI LE No, RF>.. 3 - .31.. It' :>1,,(" sTAn,llIIlSé. FORMATION DESCRIPTION ODOR FLUOI cue t.."! 1$!.. ¥3~ 2..~ 2-o! /31 ~3!. t.~ ,.~ 0 I 0 ()~-O" tI.! 1"'- 3.- ,;- I.L! 100 '" r ~ 1r 10-11 z,2. J,e4- ,.-u,- z- .,., J' ð q 'I " IL"'3 ~o to1'" IT., ¡'A/- z.- I"'_/~ lOt. z.t 2.11 f.! S'z.! z,1!- II,.. 11 ,~/,~ 2.1..! It'!· 5f! 1. ?j 1-1..,1-'9 SS"&o£. Z.-! /3! J'f':. z.~ Z,\.t.'L-1.1,t·n- %..,1 tr~ 'II! z.1,,! z." -tS' U' t.! t.1.! ,1! 'If!. z.1.1 '.1# , :S." Z¿'·Z:7 IOJ.. tor - 3"~ 3t.- to- 2.'-z.9 .¡., 1.' 12. '!. 7.1. ~ /3 ~ z.1f 3'-3) ,''' Is1 1.,1 3D! z.9î 'Z.~ 11..... 'Io!"" " 31.-) $' tel --- 3'''' 3'.... z. _ )'t..))'" z., . 3 14!: 31.~ 1L! '2. I-J 3'.37 z. t IJ 'I ~ 1.1.! .¡~.r. ~ ':! J'1- 31 '2. «I .,. ~ z. o:! t 1. !. '/1 ~ Z. ,-' 1.1 ., ~ '(0-'1' ,.r 2.1- 3'- J1~ z.~ ,.¡. £. 2 t 3S I , ~ «f\.'U t·:. 2..1- 3;)'" - z...: 1$'1/ I 1. 1.. , I} ",".'¡s 1z.. t..1-. 30.... ,.... 1. _ Þ" 1/1-1/1 "IS" " t..t! 31..!. '"' ~ z. ~ r/ 1.l-~/·4'f 413 ,~ I~!. 1./1 4'/!' z. ~ v Z.r..S1-5t ...., 9.~ z.1.!. ¡,!. f,!. z. ':! t/ lIS' 1 ,If ." ð 1-1 V .s'1-tD , '-/1. 1..,.... 2..5 __ II.J- 1.- ¿'I·/'-,.. I"'/. 3'. ".! 2,'1. ~ ~ 1!- 2. ~ ,/ - "L.'1.IJ·''f 3'" .,J Zoll.! J'.'~..!. I...' V' et) ALTERED CORE - (4) CORE CONTAMINATED .v DRILLING ,.LUID (aJ IEXJOO.ED CORK (II) REFER TO ATTACHED LIETTER .a) INIIU,.,.ICIENT .AMJOLK (II) LOW JOERMlEA81LITY 7"h-;.s h A Þ~et;'lifirt~ð"ÿ Cðþÿ "ðf lJð:tr'l St'~m"ttr1 U /,ð" Nèqllnt rHfrl /1 NrJt it p,,,,,, Rl1þ"'" . ,n 2.l..o4 . O~ s' f.~ II/. 01.-07 SS, &oJ ~" ' /1-., t/ .., r't£ "" r/ ,/ '" v' V ~ t./~ .... t/ v .... tI' ." .". ..... t/ " ." V' li ~ C l!:. V J!, V Y' v APR 191974 S " Ff 1 , I"', tI' N A VPETRES(. P..L.l'iSKA SJ, II ~1 ) s 11-1 fI' V' t»1"- ,;' v v v .. "" vi ~). u ~.¡,. s 'I;, f'1'" V' v a-' It f.A,,,~ uti -"~-<-"~---'~-""-_·_·""'-'!"~--::::;_2:'::~c:::~:'~:::::1::'::::;Z:::-:;,---,--~_.:::~~.:~::t:':":'::::'~.~~"-~;:'_~::::'_;'::~-~':;-;':::::::~~'~~__"""'~._~.~~-..- ,-, - -,--------._-,--------~_. "---~, .,--"-,,,--'-,. ._--,~.~~,.,-:._......~.: ~----. "RE LABORATORIES. u. ¡-\\¡,;\) PRELIMINARY CORE ANALYSIS Pt=Cc..\~)""'" ,',~ ..,\ ~'\¡'\i COMPANY lA... ~. Nlfvý_ ',I <.h \\\"\ 1\ 'i "',_,;, ,\ ~ ~ WELl SO. 131f/tR.:o",,¡\¡ft í 1.. .. ,--; r) :iJELD SO. 8RR.R.oI.4I COREe e. '9~V. \) \';"),':.: i~\.UJ~· D.' C. ;},'~ ,I' GAS ,.. % FORMATION DESCRIPTION VOL. j)aI~. 2. '5 SS, u h¡ I $ /f1,sl/" t 'Æ 1/ .,... V z.~ z. '.:! 1..'= ZL:! z.~ Z~ z.Id La. Z - $ S INt.? z.!!. V s,'Jt!R..lï~ z.LJ SS'~-~7 2"Z. - S!,W\-c:.1 2,': V ,~ Z- SS'""1 Z~ SS,Ç·W\11 S'''y Z !! t/ V. $ /I, 21.1 $$, P, þ s/fy.l s4J, z.?! 1/ v v 1 I..! V' v'/ L ".!. V" "'" 1/ Z.':.."<.J4 J J ~ ., I 7 ' u ~ /'1 CL~9U DRILLING FLUID IN. REC. DEPTH PERIlEABILITY POROSITY OIL ~~~~~ PROBABLE OIL H " FEET IIILLIDARCYS % pliE PliE PRODUCTION V~L. ~I , ,q"." 0.' /3 - 8.' ,'113..'&1 ,.1 151 2.2. 3 1t.J8°"~' JO /'1 - J/'I;, 5'1! leu? t. '0 SS 3.. 2.01. I/!, SSf ,&1"1.911 I/t- 2.1 "~ 1! t.~!. 2.lJØS.O¿ "1(1 33 to! I,. ~ S"S'~ 3.' '5 0 ,0/3-'" 0." 13- 7- (.1- 2'. , 0 .., 't "" 2.0Z,·"l.1., t. /. _ ~- 50- -' 3' t.D'l. '-3" . o. If I ~! fI!. .;,,.! /q,o ? ll! ~ù"... '2.03$·3l /t.So '%.1- .,. 7~ 1~ ~'t 2.o31-3~ ~:s 11 - 8...... 1//- ~3'1 ''I fþ ,03' -I/o 311.. 2.1. - .1/... ~7!. 2.86#$ z,. J/, a. 2,0,",'·'11.. '-1'-5 'Z. 7 - 7 - 50- 10 ~ 3 ..&. If 3"1.~Z5 'Z..l.! g ! I/'!. '3" Io If 2.()~S"-~L It, '2..' - 3 - 3;!. 2.ø~'·"f ", "ç lif! s ~ 'ý'l. . 13 a III L 2.Þ"I1·.ro 5- if 13 L ¿ - ¿'Io - 'l. ().$'I-sz... AI.' ~2.. I' ! ,!:,~ ~ 1..oSa-S'I All 71 /¿, ~ ¿.! "~ 2.øÁS"s:t. If¡, S~ If ~ 5~ .5,! 1-0/1-,$'8 11 1. If JS'!. S! 7/! toP/-¿ø (J.4. ø.) 1! g! ,,1, 1/1;. ¿,a'!.. Jj ~ (øJ/! nAT5" o/J'l./"I/ FILE NO.XP"¡" 32.~ COUNTY N_T' S ¡'Ope flI.TATwAIt:. ODOR FLUORE CUCE 1/ .. - ", " v II ..... v '" t/ "" 4/ v v v '" vi' " V v flll, C; ·'7,i 't iì:) ) (ii\" rill} Ct) ALTERED CORE (.) CORE CONTAMINA~1-'~ \9 "bÄ':Li¿I~ti~l-.:i~DSKA (2) EXPOSED CORlE (II) REFER TO ATTACHED LETTER (., IN8U"FICIENT 8AMPLJr es) LOW ..IERMIEA.,LITY ritV: Is ~1P",'i"'''''ìlry Cøþy 0/ Do'" S'lbmilld Upon Rtqucst alld Is Not A Filial Reþort · .,\,W ¡ 5 xfo J ;;-9' I CORE LABORATORIES, INC. í"::~, :....: ',' - fì ~ ¡;) Petroleum Reservoir Engineering '- .... ..9r ;/1í.J--' '-. .! t.' . DALLAS. TEXAS tif ''71: November 5, 1974' I.J ", ,¡C·:-- !--1;.{).£¿/ j; 1/7 ~ u.s. Navy c/o Officer-in-Charge Naval Petroleum Reserve No.4 Barrow, Alaska 99723 Attention: Lt. Commander R. V. Shafer Subject: Reservoir Fluid Study Naval Petroleum Reserve No. 4 Barrow No. 12 Well Barrow Gas Field Alaska Our File Number: RFL 74268 Gentlemen: Two subsurface fluid samples and one wellhead gas sample were collected from the subject well by a representative of North Star Engineering and forwarded to our Dallas laboratory for a reservoir fluid study. This report is a result of that study. Upon arrival to our laboratory, room temperature bubble point pressure was measured on both subsurface samples. Cylinder No. 55215, sampled at 2000 feet, was found to have a bubble point pressure of 880 psig at 74°F. Cylinder No. 55476, sampled at 1900 feet, was found to be saturated at 865 psig and 74°F. Cylinder No. 55215 was selected for the reservoir fluid study. A sample òf the reservoir fluid was charged to a visual cell at the room temperature of 75°F. Since room temperature was higher than the reservoir temperature of 51 of., no thermal expansion was determined on the reservoir fluid. During constant composition expansion, the bubble fX>int pressure of the reservoir fluid was found to be 847 psig at the r'eservoir temperature of 51 ° F. . . U. S. Navy Naval Petroleum Reserve No.4 Barrow No. 12 Well Page Two During differential pressure depletion, the reservoir fluid liberated 119 wblc feet of gas at 14.65 psia and 60°F. per barrel of residual liquid. The formation volume factor was determined to be 1. 037 barrels of liquid at 847 psig and 51°F. per barrel of residual liquid. The gravity of the residual liquid was found to be 25.3° API at 60°F. The viscosity was measured at the reservoir temperature of 51 aF. and at pressures ranging from well above reservoir pressure to atmos-- pheric. The viscosity of the liquid phase was found to vary from a minimum of 48.89 centipoises at saturation pressure to a maximum of· 118.14 centipoises at atmospheric. Separator tests were performed at room temperature and at separator pressures of 30, 60, 120 and 200 psig. The results of these tests along with the measured specific gravities of the gases flashed through the separator are presented on page six. The hydrocarbon analysis of the wellhead gas including the mol percent of helium present in the gas is presented on page seven. A portion of the reservoir fluid was charged to low temperature fractional distillation equipment for hydrocarbon analysis. The results of this analysis along with the properties of the heptanes and heavier fraction are presented on page eight. Thank you for the opportunity to be of service. Should you have any questions regarding these data or if we may be of further assistance, please do not hesitate to con.tact us. Very truEf yours. Core Laboratories, Inc. Reservoir Fluid Analysis f/~ ~I P. L. Moses Manager PLM:RL:hm 7 cc. - Addressee . . J. W. Dalton W/ W. J. Jacoby MEMORANDUM TO FILE MAY 12. 1974 Intend to conclude S. B. #11 & #12 program and S. B. #5 work.. over program by 5/18/74 Work to be accomplished during interval 5/12/74 through 5/18/74 includes: . 1. s. ß. No. 5 Work - over program Restore the well to production condition, (after well cleans up). including leaving well house and contents in-same condition as before work-over program started. 2~ S. B.. No. 13 Complete gravel embankment. Complete foundation and cellar. . Move Rig from S. B.#12 to #13, position and g~. and replace missing plywood and sheathing. 3., ' Posit.ion wanigans as follows_ S. B. #13 S. B. #7 PAD C-250 pump Shop . Head MeSI Ha11 Water Wanigan G. O. Pump O. F. Whse Schlumberger Howco Change house Geologist Tool pusher house 50/75 KW Generator Ramp ~ walk & pipe racks .' l-, 'I()O-O~ .. .. 'pba - Camp,_ Mud tank Boiler Empt.Y i 1 eds .C; . . NOTE 1. I; (1 ) (2) .'\.. (3) (4) (5) ¡ '> "...'.....:,-, ¡ I .. . . Pos'i·tioning· of rig and wanigans to include following 'work detail s: . . , Seal exhaust stacks - all engines (smoke stack of boiler) to prevent moisture getting into engines. Coil electric service lines to facilitate electric wiring between wanigans on S. B. 13 location. Same configuration as on S. B. Well No. 12. .. Clean interior of wanigans and shut doors in such a manner that they will stay closed, but can be opened without major effort. Protect all pipes protruding from openings in wanigan to preclude rust or damage to threads. , Replenish PHS gravel used on 5.B.I12 and 5. B. 113 ~fter 5/18/74 . :,.¡.·.....ì.i.....:.,J;,,: .0, 'i. . ~ .I·_.."'~..,-, ') .~. J.t.: ¡_,~,:" ~'...-_.,.;I.:I""'; ..,;~,~:(.;~.,_ ,;'I>'~ ¡ ;¡,- ¡ 'I.. ' .......,.;0;. h;'.·..(, . ·.t>.iQ,i~;·¡ _J 'oj; .'.1.. ....;. , ,"... :.... .:....-:,~: -:¡ j'i .. t II~ ¡ ~, ¡ . ",.; ,J> ì: \.' ¡. 'I..··' '.,; i \, L ) Li\,'¡ ¡: to 1 i- ¡¡I:: , ;'i' '1' 'ì,i" JACOBY WORK LIST - CARDWELL'RIG Start after June 30. 1974 Replace rotary hose. Build new mud tank wanigan. Modify mud piping to accommodate 2nd mud tank. Weld drilling line bracket. Bui1d dog house on rig floor · ,opposite side· ftom:,V:'dOOt.i". . > '¡',' ,,<~·~',',:'_,~'{.;;,~:·i·'::.:... .." Get and install steam radiator ir:adog house.:·>,:,:,;-r:¡ (¡ Get tripple chain - 1" pitch. Get spring for m~in drum clutch. Get SKW generatorfor boiler · repair boi1 New suction 6" G. D. pump. Repair Baash Ross traveling blocks. Install starter on (another) GMC Quad. Get parts for tubing tongs. Get rain caps for all engine exhausts. Repair broken runner on mud ·tank wani Change dumping' device', Mud tank. .' !:" \ ;.:, : t,,','-] d \ . ~ ,il',¡. I ¡ I II , I I II , I ! , I! , , !! ì ,:Ii I ¡Ii: I:' 1¡ I': :, ':1 'I lìl ;1 , ~ I' I ~. I;. _ '_.'.' .;)\~.:~¡ :: " ¡ -,', ,¡' -.., j.~ ,'.';j'. , .;,: ..:":.\ ;'.. .,' :~.:' 't 1;.( i ¡¡II' t i ; I i' OTHER .j ¡ '. . Y".y ,,~â,:::;:\!, ; '!:-: :"I£~;.';·1,i~-\;:'.}:, " ' . í. j;. , '11 , ' ·1 and chemicals at Point .magcobar shri nk ( i" , I' .; I !' I¡ , ~ i' , 'Ì " I I I i 'I , i 'I :1 I ¡ 1 I, Ii , . 1:1 \:; I,; I. l.. 1 \ ' '.i~ iU,j¡J; : L::~r'~~r~~ " ','I . , j ,~; , ,- \ . :'h~: ..Y'~\'l~!!\H~¡\¡i,(4j: \' 'I!!: . '. CONCLUDE S. '.}. , , )0. ' I, " "r . ~_ ';ji\';' .1.'\ 1" ~I':' " t;:~)i;\.¡t!!~-~· ,:, : 1 it , ~ ;1', ",-' :', . ~ ¡ 'f: B. 5. 12 and 13 .\;. . .... ..'\,'0"1 " , r,' :.... . , · EST. LABOR COSTS , , ) . Memorandum of 5/12/74 Interval 5/12 -,5/18/74 . ;' :-1 ,); .\ " . ,." "j ," , i,t' " ,~ ' . . ;"i'. I·i· 14 Men .. , ~ . t '. Average per man day lABO~,COST ,. ;; ';, ',i-, 'j-'" 6 days 84 Man days (12 hoùrs) = = $170.00 = 170 X 84 - . =$15,000.00 ~ :. , ·" ". "....' ! ~ '- ,'< , c"" ,. -._,~; May J2. 1974 PROPOSED CREW COMPATIBLE WITH MEMORANDUM 5/12/74' Dub Barnett 1 Steve Hopson 2 Jim Aiken 3 Josh 4 Mike Patko1sk 5 Stan Cook 6 ( , '. ~ CLI FF CREW FOUNDATION AND...DIRTMOVERS . Operators , C, 1 ff Johnson J. Ze11ar" 7 8 (if needed) . . , . F. Hi 11 MECHANIC Little Joe Da 1 e Johnson" Tirnell , Mac Davis WHSEMAN j , , 1 , \ \ I ./ , " ') , " \ ) , I " ( , ~.P , \ " \ ) \ J I ( l I I ~~ ".. '.... " \ \ \ \ ... -2./H· .. -~. "- " ; , s. B G.~rtlw M '. fOO .-, O~ -.. - -.. "'... ..-.-......... . -.. . . _il. ".- t , , \ I , , \, ') , " \ a , , " ( , ~.P , \ \, \ '-, ...., \ \ \ \ . -2.1" . -.2.2to ' " " WI. f,.1 a.rrllw "', , · · · · \ I '" lit,. ·IDD-6~ .......... -.... ... . CORE LABORATORIES, INC. Petroleum Reservoir Engineering DALLAS. TEXAS . Company U. S. Navy Well Barrow No. 12 Field Barrow Gas Field Date Sampled County State PagA 1 of 11 FilA RFL 74268 AprilIl, 1974 Alaska FORMATION CHARACTERISTICS Formation Name Mohr Sand Date First Well Completed Ma y 11 Original Reservoir Pressure 889 PSIG @ Original Produced Gas-Oil Ratio Production Rate. Separator Pressure and Temperature PSIG. Oil Gravity at 60° F. Datum Original Gas Cap , 192!... 2150 Ft. SCF /Bbl Bbl/Day of. °API Ft. Subsea Elevation Total Depth Producing Interval Tubing Size and Depth Productivity Index Last Reservoir Pressure Date Reservoir Temperature Status of Wen Pressure Q~µge Normal Production Rate Gas-Oil Ratio Separator Pressure and Temperature Base Pressure Well Making Water WELL CHARACTERISTICS KB 26 2282 2197-2264 Ft. MSL Ft. Ft. In. to Ft. RbljD /PSI @_Bbl/Day 889 PSIG @ 2150 Ft. April 11 . ,19~ est 510F. @ 2200 Ft.* 30650 N PSIG, Bbl/Day SCF IBbl OF. PSIA Ð/o Cut o SAMPLING CONDITIONS Sampled at Status of Well Gas-Oil Ratio Separator Pressure ·and Temperature Tubing Pressure Casing Pressure Sampled by Type Sampler 1900-2000 ft. Temporary Completion !':CF /Bbl of. PSIG PSIG PSIG,_ North Star Engineering REMARKS: * Temperature estimate based on data from other wells in the area. . CORE LABORATORIES, IN, Petrolellm Reservoir Engineering DALLAS. TEXAS . Page 2 of 11 File RFL 74268 Well Barrow No. 12 VOLUMETRIC DATA OF Reservoir Fluid SAMPLE 1. Saturation pressure (bubble-point pressure) 847 PSIG @ 0.99091 51 . of. 2. 5000 V @ 51°F Thermal contraction of oil . @ - PSI =v @ 75 0F- Compressibility of saturated oil @ reservoir temperature: Vol/Vol/PSI: s. From 5000 PSI to 4000 PSI = 3.95xl0-6 From 4000 PSI to 2000 PSI = 3.77 x 10 -6 From 2000 PSI to 847PSI= 4.60 x 10-6 4. Specific volume at saturation pressure: ft 3/lb O. 01811 @ 51°F. Thew-analyses. opinions or il1terpretations a1'8 based 011 observations and material supplied by the client to whom. and for whoee acluaive and eonfident" -. this report is made. The interpretatiol1s or oP!l1ions expftlllled represent the best judgment of Core Laboratories. Inc. (all errors and omissions excepted); - but Core Laboratories, Inc. and ita officers anå employ_. assume no responsibility and make no warranty or representations .. to the productivity. proper ØP'ft'II- tion. or profltableneA of any oil. gas or other mineral well or sand in connection with which such report is used or relied 111>01t. . CORE L.ABORATORIES, INC. Petroleum Reurvoir Engineering DALLAS. TEXAS 75207 . Page Filp. Well of RFL 74268 3 !l Barrow No. 12 Reservoir Fluid SAMPLE TABULAR DATA PRESSURE·VOLUME VISCOSITY DIFFERENTIAL L.IBERATION @ 51 ·F. RELATION OF OIL PRESSURE @ 51 OF. r 51 ·F.. GAS/OIL RATIO GAS/OIL RATIO RELATIVE OIL, PSI GAUGE @ LIBERATED IN SOLUTION VOLUME. RELATIVE VOLUME OF CENTIPOISES PER BARREL OF PER BARREL OF V/VFt OIL AND GAS. V/VSAT. RESIDUAL. o=~ R¡;;SIC:":AL OIL 5000 0.9831 98.33 1. 019 4500 0.9851 /' 1. 021 4000 0.9870 86.56 1. 023 . 3500 0.9889 1.025 3000 0.9906 74.75 1. 027 2500 0.9927 68.23 1. 029 2000 o. 9945 62.23 1. 031 1500 0.9967 56.57 1. 033 1000 0.9990 50.70 1 . 036 900 0.9996 1. 036 847 1.0000 48.89 0 119 1. 037 834 1.0023 828 1.0034 822 1. 0044 816 1. 0055 758 1.0203 700 53.46 15 104 1.031 683 1.0421 610 1.0748 567 1.1187 550 59.72 34 85 1. 025 467 1 . 1 844 400 67.02 54 65 1. 019 392 1.2721 332 1.4040 262 1. 6017 250 78.58 77 42 1. 013 212 1.8609 154 2.2751 108 2.9302 86 102.41 104 15 1.004 v == Volume at given pressure V."T. = Volume at saturation pressure and the specified temperaturp.. VR = Residual oil volume at 14.65 PSI absolute and 60° F. These analyses, opinion or il1terpntations· are based on obtlervations and mate rial supplied by the client to whom. and for whoee IÐtclusive and confidential u.... this report is made. The interpretations or opinions expn!ll8ed represent the beat judgment of Core Laboratories. Inc. <aU errors and omissions excepted) ~ but Core Laboratori... Inc. and its officers and empl_. assume no responsibilit7 and make no warranty OJ:' representations as to the productivity. Jm>pel' _~ tion. or pr!>litablen_ of any oil. gaa OJ:' other mineral well or aand in connection with which such report is used or relied upon. .-.........-.., "- ....... .~..-~~,~.'i._...,.-...---...,_..-.-'"..-.'ê.-._-...."...~~'.,-..~_.-:-.."""'__...,..._.~..._" ... k_ ......".~'".;........_...,._ . CORE LABORATORIES, INC. Petroleum Reservoir Enginen-ing DALLAS. TEXAS 75207 . Page File Well 4 of 11 RFL 74268 Barrow No. 12 Reservoir Fluid ~AMPLE TABULAR DATA PRESSURE PSI GAUGE PRESSURE- VOLUME RELATION @ 51 ·F.. R£LATIVE VOLUME OF OIL AND GAS. VNSAT. VISCOSITY OF OIL @ 51 .F.. CENTIPOISES DIFFERENTIAL LIBERATION @ 51 ·F. GAS/OIL RATIO LIBERATED PER BARREL OF RESIDUAL OIL GAS/OIL RATIO IN SOLUTION PER BARREL OF RESIDUAL OIL RELATIVE OIL VOLUME:, VNR . , 68 o 4.0042 118.14 119 o @6üetF . ..996 = 1.000 Gravity of residual oil = 25.30 API@60C)F. v = Volume at given pressure VU,T. = Volume at saturation pressure and the specified temperature_ VR = Residual oil volume at 14.65 PSI absolute and 60° F. These analyaes, opinions 01' interpretatiODll are hued on observations and material supplied by theelieDt to whom, and for WhOM ezcluaive and confidential UN. -this report is made. The interpretations 01' opinions ex])reøaed represent the beat judgment of Core Laboratories, Inc. (all e!'1'Orll and omisalone exeeptéd); but Core Laboratories. Inc. and Ita oll!leers and employeee, assume no responsibility and make no warranty 01' representation .. to the praduetivìt;y. :liMper 0pera- tion, 01' p1'ofttablen_ of any oil. gaa 01' other miøeral well o~ sand iø eoftøeetion with whieb such report is used or relied upon. - .,-,~_'_.""_"'.'~'" _,,...,-o___~~.~__.~.~ .>'._~ -""""",__ ....,..._.-.,_........_ ~<.__._.___ -,.--.--..., . CORE L.ABORA TORIES, IN Petroleum ReJert/oir Engineering DALLAS. TEXAS 51° Differential Pressure Depletion at Pressure Oil Density PSIG Gms;Cc 847 0.8844 700 0.8875 550 0.8904 400 0.8927 250 0.8959 86 0.8998 0 0.9048 Gas Gravity . Page File Well 5 of 11 RFL 74268 Barrow No. 12 F. Deviation Factor Z 0.606 0.911 0.585 0.926 0.578 0.944 0.575 0.963 0.585 0.985 0.682 Th...... analyseø, opinions or interpretations are based on observations and material supplied by the client to whom. and for whœe exclusive and confidential _ this report is made. The interpretations or Opinions 8X1Iressed represent the b<!St judgment of Core Laboratories, Inc. (al1 errors and omissions ..,..,.pted) ~ but Core Laboratori..... Inc. and ita officers and employees, assume no responsibility and make no warranty or representations as to the productivity, proper opera. ¡;ion, or profitableneu of any oil. gas or other mineral well or sand in connection with which such report is need or relied upon. ,",...,..,'O..,~".... _...,........_...-~'~"-,.._,__.,_.. ~____,... __. .,..,;.,-....,~+...~_,-,.~ ,_ __._ ._.__,", ._.,_~., ..~_.~ 0"" · CORE LABORATORIES, I !'Jr:. . Petroleum Reservoir Engineerit,... DAL.LAS,TEXAS Page 6 of 11 File RFL 74268 Well Barrow No. 12 SEPARATOR TESTS OF Reservoir Fluid SAMPLE SEPARATOR PRESSURE. PSI GAUGE SEPARATOR SEPARATOR STOCK TANK TEMPERATURE. GAS/OIL RATIO GAS/OIL RATIO o F. See Foot Note (1) See Foot Note (I) STOCK TANK GRAVITY, · API @ 60. F. SHRINKAGE FACTOR. VR/VSAT. See Foot Note (2) FORMATION VOLUM'E FACTOR. VSU./VR See Foot Note (3) SPECIFIC GRAVITY OF FL..ASHED GAS (Separator) 30 74 109 8 25.3 0.9551 1.047 0.608 60 75 104 12 25.4 0.9548 1.047 0.598 120 73 94 23 25.4 0.9585 1.043 0.594 200 73 82 36 25. 5 0.9610 1.041 0.596 (2) Separ,ator and Stock Tank Gas/Oil Ratio in cubic feet of gas @ 60° F. and 14. 65 PSI a bs olute per barrel of .s.tock tank oil @ 60°F. Shrinkage Factor,; VR/VSAT. is barrels of stock tank oil @ 60° F. per ban'el of saturated oil @ 847 PSI gauge and ~ 1 0 F. . Formation Volume Factor: VSU./VR is barrels of saturated oil @ 847 PSI gauge and 51 0 F. per barrel of stock tank oil @ 60° F. (1) (3) These analyMII, GpiGiona or interpretati01\O aN based on observations and m&terial supplied by the eli...t to whom. and for whOlle exclusive and C91Úidential u.. this report is made. The interpretationB or opinions expreaøed represent the best judgment Dr eo.... Laboratori.... Inc. (an errors and omi....ions excepted); but Core Laboratori.... Inc. and its officers and employees. asBume no responsibility anr! make no warranty or representations as to the productivity. proper <>perRo tion. or profitable.... of any oil, gaa or other mineral wen or sand in connection with which such ....port is uaed or relie<\ Opoll. · . CORE LABORATORIES, INC. Petroleum Reseruoir Engineering DALLAS. TEXAS Pasre 7 of 11 File RFL 74268 Company U. S. Navy Formation Mohr Sand Well Barrow No. 12 County Field Barrow Gas Field State Ala ska HYDROCARBON ANALYSIS OF Wellhead GAS SAMPLE COMPONENT MOL PER CENT GPM Helium Hydrogen Hyd¡-ogen Sulfide Carbon Dioxide Nitrogen Methane Ethane Propane iso-Butane n-Butane iso-Pentane n-Pentane Hennes Heptanes plus 0.92 Nil Nil Nil 7.88 91. 45 0.56 0.06 0.01 0.02 0.01 0.01 Nil Nil 100.92 0.141 0.017 0.003 0.006 0.004 0.004 0.175 Calculated gas gravity (air = 1.000) = O. 590 Calculated gross heating value = 934 BTU per cubic foot of dry gas at ~ 4. 6 5 psia at 600 F. Collected at 675 psig and 51 0 F. Th..... analy..... opinions or interpretations are based on obøervations and material supplied by the client to whom. and tor whoee excluaive and confidentlal_ . this report is made. The interpretaticma or opinions expressed represent the beat judgment of ('..ore Laboratories. Inc. (all errors and omissions excepted): but Core Laboratories. Inc. and its officers and employ-. assume no .--nsibility and make no warranty or representations a.a to the ¡noductivit:J'. proJ)er opera.. tion. or profttable_ of aD)' oil. trail or other mineral well or Mnd in connection with which such report is used or relied upol1. . Company u.s. Navy . Barrow No. 12 Well Fielò Barrow Gas Field CORE LABORATORIES, IN Petroleum Reservoir Engineering CALLAS, TEXAS . Page 8 of 11 File RFL 74268 Formation Mohr Sand County State Alaska HYDROCARBON ANALYSIS OF Reservoir Fluid SAMPLE COMPONE:NT Hydrogen Sulfide Carbon Dioxide Nitrogen Methane Ethane Propane iso-Butane n-Butane iso-Pentane n-Pentane Hexanes Heptanes plus Cylinder fu. S5215 MOL PER CENT Nil Nil 0.56 22.34 0.97 0.31 0.12 0.41 0.16 0.07 1.02 74.04 100.00 WEIGHT· PER CENT DENSITY @. 60· F. GRAMS PER CUBIC CENTIMETER · APt MOLECULAR @ 60· F. WEIGHT Nil Nil 0.07 1.50 0.12 0.06 0.03 0.10 0.05 0.02 0.37 97.68 100.00 0.9055 24.6 315 Core Laboratoríes, Inc. Reservoir Fluid Analysis P f JI!~ ¡¿Ã P. L. Moses . Manager Th...... analyses. opinions or interpretations are based on obsel'Vations and material supplied by the client to whom, and for wh_ exc1"¡ve and eou6deøtial -. this report is made. The interpretations or opinions expressed rep1'1!!l8nt the best judgment of Core Laboratories. Inc. (all erl'Ol'S aDd om!8IIi_ exeepte.n: but: Core Laboratories. Ine. and its officers and employ-., assume no responsibility and make no warranty 01' repl'8Mlitations ... to theproductivity.~ CI'pIII'8o' tion, or profitablenl!llll of any oi!. gas or other mineral well or sand in connection with which such report is used 01' relied upon.. . 4.0 3.0 '" > " > ¡;,,¡ ::2 ::> ...J o > w > ¡:: :s w a::; 0..0 . CORE LABORATORIES, J. Pecrokum Re.senJOiT Engineering Page DALLAS. TEXAS File PRESSURE-VOLUME RELATIONS OF RESERVOIR FLUID 9 of-1.!.. RFL 74268 Company U. S. Navy Well Barrow No. 12 Fjeld Barrow Gas Field Formc¡tion Mohr Sand County State Alaska ¡ I ¡ II , t I -0-1 I II , I I ! i ! ¡ ¡ i , : ¡ I í ." r , ' I I ~ ! -~-1---: +-¡ ! , i, , i ¡ :~+-'! 2~-¡ : · ~ ~ '; ¡ ! : i t I =-=;-:- T· ¡ , I J ! 1 ) ~-+-+- ¡ .+-+ I -..--+- ....¡... H··~-r··t 2.0 _.-. 7""! : ~ ---¡OJ -, ! : ! ¡ i ! ¡ i __.l-...L-J.. i ! i! ¡ ¡ -H i . " , ! ! I · . I : I +¡1 " I ¡ ! , : I I ì -+-, I I ; I _":...L ~ I ~:¡¡ · '!! 1.0 , , , ' ; t -:-1 : ¡ ~¡ ~ ) " ! -+-r _ t I ; : I , i : !, ¡ , --t~ , I ¡ , I' " : I ¡ I -L! i I --I ¡ I , I , I ~!! ~! ! 'I' ! , I - ¡ ! III! o ì r I I i i ! I , I , , , I II : I I I , I I, I --n- ! I! , t ¡ ¡ r r : -II I I I ! ,I II, II I I I I ¡ : . I I I' I :, ' I 'I! , , I' I , I I HII 11- --t-i I I I II 1II1 I I! I' I I+---f+l+- r ¡ I, ,I I I -W-1=±+-+-t I II' I I' I,! I I I I I! ! I ~ 'I I I I ¡ !. I I . i r II I ¡ i; i I il': I ! f ¡ I I! : I ¡ r :, ! I It ,-II I ¡ ¡ I r! I ¡ f i! ¡ I I ¡I I ¡ I l! ¡ 1 ; ¡ I :- ¡ ;. ¡'II ; I I ¡ I ¡ , ¡¡¡I : i !; ¡' i ill' t; Ii I i ¡ ~ ¡ . i I ; I' I I ,¡ I I ¡ : I i ¡ !! I ¡ I I, f I I I; I I ; I ¡ ~,¡ ! . I ! I I 1+ ¡ I r I' -t-t I ¡ r' II ! I I I I I' I I, I . I 'II ++-r--t-t-~¡-r--; I t I ,-t+;-¡-.-.p+7-+-1, I! [" ! I ¡ ,I I I" ,I I I I . I I I,' I I I I I I I I" I I :!: ¡I: ¡ il: ¡ i ¡!'! H+: ¡ +-~t+ 'II ¡ ¡ ¡'II! -Jh- ! I ~'i, l ' . ii' ¡. I. ¡ i ; !: ¡,: i! ; . I' If ri " Ii, ¡ : : It: i . i I ;" ! I .; .L I' i I '~. 1tt' -r--¡t-I ! '~ I . 'I " I I' ' . , , I, ¡- ,ï , , ': I I t- I -;--: ,,- ~, I ['I" ' : f t r t ,I!I I" I I . 'I'''' ¡ I· I l I I! Ii', I ¡ I _L.U: 'I ¡ f: ¡ -+++-, ' " I I ¡ ¡ i I" l :, I ! I' i '--t-+-H--,', :---r:-rl :11 r "1,1 tll! ,II Iii li[ I' I,,!III! ; ¡I[" ,,:1', t i 'Ii! -¡--n-¡-,,'Ii, 'ill", Iii i I It! Iii' I ' I t I,'!: I; r, '! t t 1.1 ! II ---; I! I I I I I ! I : I I t I !' !'!: I !: ì ¡ I I I! I I ¡ i : :: i: . I :: I. I I' I If' ¡it ¡I¡: :'Iit :¡[! -¡;--r¡ ¡¡Ii ¡¡-¡-r-It I . ,t¡fll I -r-l-+-t--:¡ I I: Irli :!-r--r-++t-+··¡ f' I fl i ! I r ' ¡: : I tit' ì : I I ! I ì -, 1 , t r ; It I '- i ¡! I I 'i-+ I " I,,! I I It! 1'1' I:: 11,1 ¡ t , ' " I T t I It" I l' I : r .-, I r I r ~ I I I I ¡ ¡ ¡ i-I! ¡ I It ¡ ¡ Jr' -=r1-l I ¡ I ¡ : It II ¡ ¡ I I ¡ I ¡+h-: ! '! !! I I I I ! - ¡ i I' !: !!! r I l ø I -+-'-1, . I! . " ¡ ; If--: i f I I " ,I, ' I .' . I : I I I I I', I" ¡ '. "I ,. ¡ , · +--L-! I" I '; ,; I 'I" " I "i I I I . I ' t-t · ! iI "I . I: I I ., I! " I: it' I , 5', ~ ~\.11 ,a;t o~ I! -1 Ii:' Î ; I " ! ! I Ii, I I ! I . '-I:, ¡-=+---¡--',' I ¡ I ! I I ¡ : I-~! : I r. t' 1-11 . I t I I :, 'll:~!II M\~i ¡I, I I' i r- ,,;, ,I ,I I I t ¡ ! I, ,8'4'7 PiilO I i ¡ r I J i I ¡ 'i; i ! I I ,!! I ,I I I! ;. ,! r i , ¡ I, í r i \ ¡ ',: i; it; I I-+Tr-.... " 1+', I' I I II ., . ! ! t t !, t l II I II i t ¡ II I I ¡I ·1 :-t-tl-i-t-t· '~- II I I ¡: I 'I' I : . ! 1 I i I ;' I II 'I'" I, I I' ït· f ,: · '" I I : I [I I! ¡,I ' !! 'I : _[-~T~i--¡rr i . ¡ I,' I' ¡ r I' ¡ !;! I' I ¡ I I ' ¡ , ¡ . I! ¡ +H--+-+-+ :-Li-++-+~- ' I! t ~ I," : Ii' I I. II ,.l " -> ! I '¡! " ¡ Î, l i l, ¡ ¡. , ! llf ¡ :,. ¡ l ¡ . '!, I!..'! 100000-br If! ¡tlr f ¡ f r [¡lldr ' r It! !I'I!o l' r, 111!f~ ¡I, I ¡¡'0 I II ¡lfl~l· iI, I ¡O'f . Ii ¡ j ¡ II ~, 'I r' -1L I ! I I I I ',! ! ! ! ! , , :, ¡! I ! i I f I, [ I :' I ¡ i, I,'" r I i ! I I , I! I I I I ¡ I! ¡ ! ! ¡ I · I: I ! " ! : I I ¡ , l' ,, I I ,I 'I I II: j Iii I'! ¡ I III II! Ii: ; ii' i Iii II ' I , Iii, I I I I I I ! I i' II i I r II I It I ! 1000 2000 3000 ¡ I I I ! I i I I ; I ¡ I I ' I· I ! PRESSURE: POUNDS PER SQUARE INCH GAUGE 160 140 .....1 Õ .....1 < ::> Q tñ t..J II: ¡., o .....1 t..J II: II: < co II: t..J P.. E- t..J t..J ¡., u ã5 ::> u Q II: < Q Z < E- U] o t..J E- o:( ::r:. :..¡ :1J ::¡ ~') < ~ 120 100 . . CORE LABORATORIES. INC. P¿cf'olium Pf1t.'''''Joi., EnKln:!ering DALLAS, TEXAS Page File U[FT".:fU:\T!.~,L .¡ A''';i'jZATiC)~: or RE.':E!ìl''::'lR FLUID Company Well Field u. S. Na vy __________ _ F·;,:~-,:.:tj'~n ._yohr Sand Barrow No.-1~__________._ __h_ Cc;'mty ____ Barrow Gas Field ~~tate Alaska -.-----.-.---- ------- 80 llii! ,. ¡ ; If; 'I ¡ I I'; :' ¡ j, ' I I· I; ,': '1- I I I' : I. . -r-r---t-t ' , , - -¡- .-~-+ ~ i-r- 1"-. t t . -+ .. .- + +-ït -~-+ t-+- 'I' Ii, I' l -r--t- -+-t .J-+_ t-Ti ~.- L )-._.l- - h->-t -i-L I __L+-t' u!... I ¡ I I -I-4-+-L·-........¡...T~-:..~ l._.___+ -t-n' ~ i 'I ! , .' I It! I , " I· I : ··11" I I -- --- - -. '''+---r-'''~- - +---, . , .. -. '-- .--t, t I ,¡. :! I, I ,¡ r ¡ f I f · t I . I I I T-r++-++-H--~~ ~ ~------rH--' I ' II , II-~r+r-- tt-' i I I ! i I U t . ¡ . , I' I·· -+-+---t : II ¡' ¡ t _.1 ~+-+---l-LI: ~---: I II I I I I I ! +-+-t+ ~..;...~--. +---t-+- I ! I -t I' I I I' ,', , ¡ I : I ,;, I': I ¡ ,. I + f!' 'I t ¡ I' . ~" '.. I 'I I .----r--t+-'~~ t+-..+¡-+--h...... ~ 1 I I' I , I-+-+-'- --t-+-+...L...----r l' .."..~ T- .........~--- ~ f _ I ¡I I " i +- L_:-+-+-~ ! t t I ......+-1 ¡' I i I +++ I I', I Il.-L- '1'" I I -¡: : : ~' It ii'!: t-r-¡-t-t --~~-t-t ..-r;~: ¡ r ~.: -+-H- . t I I-U' I ........f-j...4--!--~ M --~ +-,+-- ~ I I' r' f --w--+~+.- t t t . I I ¡ iJJI: ; ~-¡ ~--++-t-+ ;; ~! ~ t ~ \ -t+H-- li-+-+-"· __.,..L_--'-.). -i-l...:-'-r--~-t-.t- i ; I I . ¡ I ¡ . ('J-+.'·-11-- I. I , i-r-Tttf-~T~t-i-rTr--~+t-·-"r-.¡.·r:-;-¡-tt ¡ II! . ""-+-~+_. I . 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II' ¡' i J 'I II 'I t : J , I . ¡ : ¡I' --;.....;...----T~+T :! \ ,i ¡ ! 'l; ill ! I ~ ' ;!!! ¡ t': ,¡;, 11· I I : ! ,I -t I I I : , +i-tî~·~- H-t--~--I-' I I -Ij II ¡:¡il ¡Ii! ill,!! II1I in I. iii,' II I I !!' I h- l....-..4rl' I " .". ¡ , ! I' . ¡ I, ¡! ¡' I I I . I! . I ' J '! ¡ ; : ¡ ¡ ¡ i ; ! I I' I I I! It' r ; I I í I \g. .-hJ.-l"7'-:--- t'11-T--P-TT-'7î--r -;-r-r-r I I it- Ii i ,~~I 111rnTfîtìt:¡-¡-t im-I ¡ o 1000 7000 60 I i . . ~ I ! j ¡ I i , I t i'} t : f i . } i t - i ~ f ! ;.. I ¡ ¡ I i ' I ! II I ! 40 20 o PRESSURE POUNDS PER S:JU ARE INCH GAUGE -10 of~ RFL 74268 ¡ f ! t tt ¡ ¡ I I. ~ é . ! ¡ I ~ I I ! II ' , f I ¡ - ¡ ¡ I 'i ' , I ¡ I I ¡ II ¡ I , I I t . l ¡ ¡ . . . I f I ' l . ! I i II. ì ¡ ! I , I ¡ . ¡ Ii I I! , I . ' : II I t 11 3000 L06 1.05 , " 1.04 , I . ~ I ' ¡ i ,1.03 ·1..02 e;; > -...... > ~ ::1! ~ .....J o > Q 5 o :1 EiJ > ¡:: õ( .....1 t..J II:. ') , , 1. 01 1.00 " , I 0.99 , ,. l I I - 0.98 120 110 100 . . Page File 11 of 11 RFL 74268 CORE LABORATORIES. INC. Petroleum RejeT'\loir Engineering DALLAS. TEXAS VrSCOSITY Of RESERVCHR flUID Formation County State Mohr Sand Company U. S. j'Tavy Well Barrow No. 12 Field Barrow Gas Field , i 0: I - t') ¡ i - ¡ 90 .;. UJ \ úJ UJ Õ I i 0. ~ z 80 úJ u :>.: I- ¡¡¡ 0 U UJ :;: 70 60 - I 50 40 o Ala aka I I I II i I I ~ I I I I I , I i , ¡ t ! . f ì ( ; ! ! I , , I I ; i .; ! I ~ -I i I I ¡ ,;. i I ¡ ! I , I l I - I ! f , ! ! I I· I i ~ ! i I I I I i ! ! ¡ I ! I I ¡ I , i (: ( , , ! I I I i í I i i , i - ¡ I . . .. I I I ·:·.·.IA, Ii __~~_'Ii U! i .¿(", 1 . I I ' , ' .:! I'. '. I ' Irr----t----t +----: -~. , i i>-' .. I +.L~ I_n_~+__~ _.__ L I-.i..l-t ~; . ~~~. :. . .;' : I' -4 + i -~- - - r t-·-: ----¿ --.::1.. ¡. - L-t i 'I I -- I ' I i I : I : --- -.- ---¿---¡--+--¡-- I ,I I i ,I III' ,¡ ~ '! I SúÌ\...rat1.,;¡. I ! I ; ; ': 11 I . :f1-~l~J~~ III - ~- r-rp:6- I ¡ ~~-;'-n?;ït;lt-t~ - -·-T----- -t-u: I I : ¡it III ¡:~~-~--7f¡---- -l :~--~!I , I ' I I I I I ' I I ' I ¡ I , ' , , I I, i ! I ! I I I !\1., ! ¡ i I: VI" Iii i I i 1\ I I: I VI i ! I ì : : : . I i L--(' i ,i I 'I I' . !!'~íf!I!: i II i I . ¡ ¡ I I i I ¡ ¡I! ¡ ! i I : I 1000 ! i ! I ¡ ! I I f I I I I \ I I I , ,. ! i I ¡ I 2000 \ , I I ¡ 1 I ¡ 3000· PRESSURE. POUNDS PER SQUARE INCH GAUGE . . SOUTH BARROW TEST WELL NO. 12 ESTIMATED FORMATION THICKNESS AND DEPTHS By Clifford L. Mohr February 27, 1974 At the No. 12 location, the maps and report of the recent seismograph work indicate that the depth to the Cretaceous-Jurassic contact is approximately 1550 feet, that the Barrow gas sand immediately underlies this contact, that Upper Triassic rocks probably are present, and that the top of the argillite "basement" is near 2340 ft. The geological data from South Barrow Test Well No. 3 and Avak Test Well No. 1 suggest that the depths and presence of some members of the stratigraphic column at the No. 12 location might vary considerably, more or less as indi- cated in the following tabulation: FORMATION TOP DEPTH RANGE (ft) THICKNESS (ft) Pebble shale 890 - 1490 400 - 600 Jurassic 1550 - 1890 o - 100 Prospective Gas Sand 1800 - 2100 o - 90 Barrow Gas Sand 1890 - 2190 110 - 150 Lower Pliensbachian 2190 - 2340 o - 50 Sinemurian 2040 - 2340 o - 60 Hettangian 2100 - 2340 o - 60 Upper Triassic 2160 - 2340 o - 180 Argillite 2340 1500+ In my opinion, the seismograph depths to the top of the Jurassic and the top of the Argillite will prove to be nearly correct; but depths to the Barrow gas sand and other intervening formations might be very questionable, owing to the presence of four or five unconformities. o - 208 208 - 211 211 - 220 220 - 230 230 - 240 240 - 250 250 - 280 280 - 370 370 - 390 390 - 440 440 - 460 460 - 480 480 - 490 490 - 540 540 - 620 620 - 630 630 - 680 680 - 690 690 - 740 . . SOUTH BARROW GAS WELL NO. 12 Sample Description by C. L. Mohr No samples caught. Bottom of conductor casing 159. Gray clay, traces of cement and fractured pebbles. Upper Torok formation. Gray clay and silty clay, occasional chert pebbles. Drilled rough like conglomerate. Gray clay, very good sample. Gray clay, trace of silty clay, one broken chert pebble which would appear to be residual from under the casing shoe. Gray clay and silty clay. Gray silty clay. Gray clay. Gray clay, trace os silty clay. Gray clay. Gray silty clay. Gray clay. Gray clay, trace of silty clay. Gray silty clay. Gray clay. Gray clay, several dark chert granules 2 to 3 rom diameter Gray clay. Sample lost. Gray clay. 740 - 750 750 - 760 760 - 770 770- 800 800 - 820 820 - 830 830 - 930 930 - 940 940 - 990 990 - 1000 1000 - 1010 1010 - 1030 1030 - 1040 1040 - 1045 1045 - 1070 1070 - 1080 1080 - 1090 1090 - 1100 1100 - 1150 . . Gray clay, some slightly silty clay. Gray clay, trace of siltstone. Gray clay, one dark chert pebble. Gray clay, traces of fine hard siltstone not seen above 770. Probable disconformity at 770, underlying formation Middle Torok. Gray clay and darker gray clay shale not seen above 770. Gray shale and very fine shaly siltstone. Gray clay and shale. At or near 770 there is an abrupt change from pure gray clay to distinctly darker and more indurated material having the common characteristics of a shale rather than the massive clay which occurs above this depth. The implication is that the two types of material were deposited under different environmental conditions and are separated by a disconformity. Sample mostly gray clay or silty clay like that above 770 with minor embedded cuttings of dark gray shale. Gray clay shale. Microfossils (?) 960-970, small thin shell fragments 980-990. Gray shale. Gray shale and silty shale. Gray clay shale. Gray shale, two chips of white flint from a broken pebble. Gray shale, trace of very fine siltstone, slight kick on gas detector. Gray shale. Cemented 103A inch casing at 1067 ft. and got returns. After 36 hours found cement soft. After 68 hours drilled cement. Gray shale, a fragment of coarce round frosted sand em- bedded in a shale matrix, trace of cement. Gray shale, trace os silty micaceous shale. Slightly silty gray shale. Gray shale, moderate kick on gas detector. 2 1150 - 1160 1160 - 1170 1170 - 1190 1190 - 1200 1200 - 1210 1210 - 1220 1220 - 1230 1230 - 1240 1240 - 1250 1250 - 1260 1260 - 1270 1270 - 1275 1275 - 1280 1280 - 1285 1285 - 1290 1290 - 1320 1320 - 1420 1420 - 1430 1430 - 1440 1440 - 1450 1450 - 1470 1470 - 1480 1480 - 1490 1490 - 1500 . . Gray shale and slightly silty shale, gas kick. Gray shale, gas kick at 1175. Gray shale and slightly silty micaceous shale. Silty gray shale, one frosted quartz grain. Clayey siltstone with a few embedded fine to coarse frosted sand grains. Shaly siltstone. Upper Torok. Shaly siltstone and gray shale. Unconformity 1225. Gray silty shale. Middle Torok. Gray clay shale, trace of pyritized organic matter. Very finely silty light gray clay. Light gray silty clay and clayey siltstone. Light gray silty clay and clayey siltstone. Drilled faster 1267-1275. Circulated. Gray shale. Drilled fast 1275-1280. Circulated. Gray shale. Gray shale, some silty shale. Gray clay which balls up on bit. Dark gray clay shale. Same with abundant pyritized plant remains. Dark gray shale. Dark gray shale, a little sandy pyritic shale with occa- sional embedded coarse frosted sand grains. Dark gray pyritic shale, one broken quartz pebble. Dark gray silty shale. Dark gray pyritic shale. Dark gray shaly siltstone and shale, slight traces of medium grained sand and pyrite. 3 1500 - 1510 1510 - 1520 1520 - 1530 1530 - 1540 1540 - 1550 1545 - 1555 1555 - 1560 1560 - 1570 1570 - 1580 1580 - 1590 1590 - 1600 1600 - 1610 1610 - 1620 1620 - 1630 1630 - 1640 1640 - 1650 1650 - 1660 1660 - 1670 1670 - 1680 . . Very dark gray silty shale, trace of very fine rounded sand probably reworked from the Jurassic. Very dark gray silty to sandy shale, trace of to very fine angular to rounded loose sand. Dark gray slightly shale. Samples are poor because of having shale from 1300 to 1500 feet. Dark gray finely sandy to silty shale, occasional coarse quartz grains. Dark gray silty shale and shaly siltstone, trace of fine hard sand. Grab sample from shaker screen. shale. Show of gas 1545-1557 on Cl -.120,000 PPM Cz 1,400 PPM C3 280 PPM C,+ SOO PPM Slightly silty dark gray gas detector: Very fine shaly sand and dark gray shale. Fine shaly snad with occasional medium to coarse frosted grains, much silty shale, trace of pyrite. Dark gray silty shale, much fine shaly sand. Silty, shaly sand and very fine shaly sand. Very fine shaly sand and silty shale. Dark gray slightly silty shale, some fine tight shaly sand. Dark gray shale. Very fine hard silty sand, trace of dark gray shale, a few granules of quartz and chert. Fine tight shaly sand with occasional dark chert granules, some silty shale. Fine hard shaly silty sand. Dark gray shale, a little siltstone. Dark gray silty pyritic shale and very fine shaly sand, trace of frosted granules like those int the "Pebble Shale." Fine hard sandy siltseone, some very fine free sand and 4 1680 - 1690 1690 - 1700 1700 - 1710 1710 - 1720 1720 - 1730 1730 - 1740 1740 - 1760 1760 - 1770 1770 - 1780 1780 - 1790 1790 - 1800 1800 - 1810 1810 - 1820 1820 - 1830 1830 - 1840 . . silt, a few dark chert pebbles as in the "Pebble Shale." The shale and siltstone resemble the Middle Torok. Dark gray shale and silty shale. Very fine shaly tight siltstone, some very fine porous sand with a few quartz and chert granules. Fine silty sand with a few medium-size grains, a few quartz and chert granules, much silty shale. Very fine shaly siltstone and grayish black shale, trace of medium grained rounded sand. Some of this material closely resembles the "Pebble Shale." Above 1710 the sands and siltstones more closely resemble the Middle Torok. Probable unconformity and top of Middle Torok near 1715. Possibly this unconformity occurs as high as 1640. Gray-black shale with occasional embedded coarse sand grains. "Pebble Shale." Grayish black shale, sandy shale, and shaly sand with fine to medium-size grains and abundant large frosted quartz grains typical of the "Pebble Shale." Grayish black pyritic shale, fine to medium-grained sand with abundant dark chert granules. Grayish black shale with numerous embedded dark chert and frosted sand granules. Very good sample. Black shale with broken chert pebbles, trace of hard sand. Dark gray silty shale (all cavings from Middle Torok). Shut down to clean plugged flow line. Badly contaminated sample. Some grayish black shale with dark chert granules. Mostly cavings(?). Grayish black shale with quartz and chert granules. Light gray finely silty shale and very fine siltstone unlike the "Pebble Shale" but more closely resembling the Jurassic. Unconformity and top of Jurassic 1810. Light gray silty shale and shaly siltstone with occasinal quartz and chert granules from above. Light gray silty clay and clayey siltstone. 5 1840 - 1845 1845 1845 - 1850 1850 - 1860 1860 -1870 1870 - 1880 1880 - 1900 1900 - 1910 1910 - 1920 1920 - 1930 1930 - 1940 1940 - 1950 1950 - 1960 1960 - 1965 1965 - 1985 . . Sample lost on trip at 1845. Circulated to clean hole and remove trip gas. Very fine shaly silty sand, a little free trace of pyrite and coarse quartz grains. of gas near 1847. porous sand, Small showing Very fine subangular to subround sand and siltstone, part of which appears to be porous. At least half of sample appears to have considerable clay matrix. Lithology is typical of upper part of South Barrow gas sand. Very fine, very argillaceous siltstone. Gray flaky shale and silty shale. Very fine argillaceous sand, some gray shale. Very fine argillaceous sand, considerable loose sand. Very fine argillaceous to very argillaceous sand. Very fine subangular to subround sand, some clean porous sand. Very fine argillaceous sand, some clusters of porous sand, a little free sand. Very fine argillaceous sand, more clusters of porous sand, more free sand. Very fine argillaceous sand, increase in porous sand, faster drilling 1955-1965. Circulated 30 minutes. Slightly argillaceous to clean loose sand. Core No.1. Recovered 20 feet. Cores have good odor of gas. Lithologic details: 1965 Very fine subangular to subround quartz intimately associated with very fine quartz siltstone, no apparent clay matrix. Dip about 5 degrees. 1967 Like preceding. 1969 Like preceding. 1971 Fine subround to subangular quartz sand with many dark chert grains, no apparant clay matrix. Dip 6 1985 - 1986 1986 - 2016 . . 3 degrees. 1973 Fine sand like preceding but with less silty matrix porosity. 1974 Similar to preceding. 1976 Very fine hard siltstone without indications of porosity. 1977 Fine to very fine subangular sand somewhat porous but with matrix of silt. Dip about 4 degrees. 1979 Fine to very fine subround to subangular sand with extremely silty matrix. Dip about 4 degrees. 1981 Very fine frosted silty sand, no bedding planes. 1983 Fine subround frosted snad, less matrix silt and better porosity than proceding. 1985 Very fine sand to very fine quartz silt, poor porosity. Reamed. Core No.2, recovered 30 feet. 1986 Siltstone, slight clay matrix. 1987 Very fine subangular sand, finely silty matrix 9 minutes per foot. 1989 Fine subangular sand, very slight matrix. 2 MPF. 1991 Very fine subangular sand, very slight matrix 3 MPF. 1993 Fine sand, many black grains, slight silty matrix 2 MPF. 1995 Fine subangular to subround sand, coarser and cleaner than preceding. 1 MPF. 1997 Fine sand like preceding but with more matrix. 2 MPF. 1999 Fine to very fine sand, silty matrix. 2 MPF. 2001 Like preceding. 2 MPF. 2003 Very fine sana, bedding planes of fine silt. 2005 Fine subangular to subround relatively clean 7 . . sand, dip 5 degrees. 2 MPF. 2007 Very fine silty sand, many black grains, 2 MPF. 2009 Very fine silty sand with slight clay matrix and trace of pyrite. 7 MPF. 2011 Like preceding. 3 MPF. 2013 Very fine silty sand. 5 MPF. 2015 Very fine silty sand. 5 MPF. 2015 - 2016 Drilled, no sample. 2016 - 2046 Core No. 3. Recovered 30 feet. 2016 Fine silty sand, low porosity. 5 MPF. 2018 Very fine sand with very finely silty matrix, faint configuration on bedding planes resembling plant remains. 4 MPF. 2020 Fine subround frosted sand with very silty matrix. 3 MPF. 2022 Very fine sand with very silty matrix, plant remains. 4 MPF. 2024 Like preceding. 3 MPF. 2026 Hard shaly siltstone, impermeable, dip 5 degrees. 7 MPF. 2028 Very fine subround sand, rather silty matrix, well preserved pelecypod. 3 MPF. 2030 Fine frosted sand with many dark grains, moderate silty matrix, trace of soft green glouconite, 3 MPF. 2032 Medium-fine frosted sand with very little silty matrix, no bedding. Well preserved pelecypod andgasteropod at 2033. I MPF. 2034 Medium-grained frosted porous sand with very slight matrix material. I MPF. 2036 Medium-fine frosted sand with many black grains and slight matrix material. I MPF. 2038 Medium-grained subround frosted clean porous sand 8 . . with many dark hard grains resembling the argillite basement, trace of soft green glouconite, dip 7 (?) degrees. 3 MPF. 2040 Like preceding. 2 MPF. 2042 Medium-grained frosted clean porous sand. 1 MPF. 2046 Medium-fine frosted sand, apparently quite porous but with distinct silty matrix. 4 MPF. 2048 Medium-grained subangular to subround frosted porous sand with matrix of very fine silt, trace of glauconite. 1 MPF. 2050 Like 2048, 1 MPF. 2052 Medium-fine porous sand with faint oil or gas stain and silty matrix. 2 MPF. 2054 Medium-fine porous sand, silty matrix. Unconfor- mity 2054. Base of Barrow gas sand 2054. 3 MPF. 2056 Fine tight sand with very silty matrix. This probably is the Simemurian. 7 MPF. 2058 Very fine dark silty sand with silty and clayey matrix. The general aspect of this material seems to contrast sharply with that above 2054. 6 MPF. 2060 Gray-black very fine silty argillaceous sand with pelecypods and pyritized plant remains. There are no distinct bedding planes, and dips cannot be measured. 8 MPF. 2062 Fine subangular to subround silty and slightly argillaceous pyritic sand. 7 MPF. 2064 Black argillaceous siltstone with pyritized plant remains, pelecypods and ammonites. 5 MPF. 2066 Very fine silty subangular dark gray sand, apparent- ly impervious. 6 MPF. 2068 Very fine subangular to subround silty sand with matrix of very fine silt, apparently impervious. 4 MPF. 2070 Like preceding. 2072 Like preceding. 9 2076 - 2101 2101 - 2110 2110 - 2120 2120 - 2129 . . 2074 Black shaly impervious siltstone. 7 MPF. 2076 Dark gray shaly impervious siltstone. 8 MPF. Core No. 5 2077 Very fine subangular to subround sand, finely silty matrix. 5 MPF. 2079 Gray-black slightly shaly siltstone, dip about 5 degrees. 5 MPF. 2081 Dark gray shaly sitlstone, pyritized plant remains. 7 MPF. 2083 Gray-black shaly siltstone, ammonite. 9 MPF. 2085 Gray-black shaly siltstone. 6 MPF. 2087 Gray-black shaly pyritic siltstone. 4 MPF. 2089 Gray-black shaly siltstone. 5 MPF. 2091 Like preceding. 12 MPF. 2093 Like preceding. 10 MPF. 2095 Like preceding. 8 MPF. 2097 Very fine frosted silty sand. 5 MPF. 2099 Gray-black siltstone. Dip appears to be near 4 degrees. 6 MPF. 2101 Gray-black shaly siltstone. 5 MPF. Drilled very rough 2103-2110. Circulated 20 minutes. Medium to fine-grained sand with very hard quartzitic streaks and limy matrix, trace of siderite, gas show on detector, no odor upon heating. Drilled rough in spots. Circulated 25 minutes. Fine to very fine hard slightly tiny sand with a few quartz granules, some loose angular to rounded frost sand, traces of quartz granules and pebbles of light greenish-gray shale, trace of brown vuggy dolomite or siderite. Circulated 15 minutes. Mostly siltstone, some fine sand, occasional quartz granules, trace of dark gray shale. The sand is lithologically almost identical with the known Jurassic Pliensbachian sand above. Nothing distinctive of the Triassic is yet recognized. 10 2129 - 2131 2129 - 2135 2135 - 2138 2138 - 2140 2140 - 2145 2145 - 2150 2150 - 2155 2155 - 2163 2163 - 2192 2163 - 2167 . . Grab sample. Very slight showing of oil and gas on wet sample. Three small gas shows on gas detector. No odor recognized on heated sample. Fine subangular loose porous sand; rare granules of dense lime, white oolitic lime, chert, and quartz. No visible oil stain. Similar to prceding, no visible oil stain or gas odor from heated sample. Fine hard limy and shaly sand and siltstone, a little dark gray shale, trace of broken chert pebbles. Pro- bable unconformity and possible top of Upper Triossic Shublik formation 2137. Gray shale, much fine hard limy Sðñ~, a few chert pebbles from conglomerate above 2137. Contrasts sharply with material above 2137. Gray shale, some fine silty sand. Sandy silty and limy shale with a faint greenish cast, some limy siltstone, pelecypod. Finely conglomesotic limy shaly sand, much gray limy shale with abundant microfossil casts, trace of hard brown to buff lime, rare chert pebbles and coarse sand grains. Gray shale and shaly fine to coarse sand with granules and pebbles of brown and black chert, white oolitic lime and quartz. It is not clear at this point in the drilling whether there is an unconformity near 2163 representing the base of the Jurassic and top of the Triassic with the interval from 2137 to 2163 a thin Jurassic remnant such as the Hethangian or whether the conglomerate be- tween 2137 and 2163 belongs with the congomerate above 2163. Core No.6. Recovered 25 feet. No recovery. 2167 Started coring slower at 2164. Very shaly black siltstone. Unconformity near 2164. 14 MPF. Top of Triasssic 2164. 2168 Black shale. 12 MPF. 2169 Black silty shale. 11 MPF. 2170 Black silty shale. 11 MPF. 11 . . 2171 Black silty shale. 11 MPF. 2172 Black silty shale with pyritized plant remains. 12 MPF. 2173 Black shaly siltstone. Doubtful dip 7 degrees. 12 MPF. 2174 Black shaly siltstone. Dip 5 degrees. 12 MPF. 2176 Very silty blackshale. 17 MPF. 2177 Black shale. 13 MPF. 2178 Very shaly black siltstone. 15 MPF. 2179 Very silty black shale. 15 MPF. 2180 Black shale. 15 MPF. 2181 Black shale. 15 MPF. 2182 Black shale. 11 MPF. 2183 Black shale. 10 MPF. 2184 Black shale. 14 MPF. 2185 Black shale. 14 MPF. 2186 Black shale and light gray subangular limy clayey sand. 12 MPF. 2187 Light gray limy clay with medium-grained sub- angular sand. 15 MPF. 2188 Black shale. 13 MPF. 2189 Black shale. 14 MPF. 2190 Black shale. 15 MPF. 2191 Black shale. 15 MPF. 2192 Black shale. 15 MPF. 2~2.,2ð ? 2192 - 2222 Core No. 7. Recovered 28 feet. 2193 Black shale. 20 MPF. 2194 Black shale. 19 MPF. 12 . . 2195 Black shale. 14 MPF. 2196 Black shale. 14 MPF. 2197 Black shale, plant remains. 15 MPF. 2198 Black shale, slightly silty with pyritized plant remains. 11 MPF. 2199 Black shale. 14 MPF. 2200 Hard brown shale. 14 MPF. 2201 Hard brown silty shale. 12 MPF. 2202 Hard brown fossiliferous sandy lime. 10 MPF. 2203 Brown limy oil-stained fine to coarse sand with a few quartz granules. The oil in dark brown and low gravity. 8 MPF. 2204 Medium-fine soft porous oil-saturated subangular sand. 4 MPF. 2205 Fine porous oil-saturated sand. 2 MPF. 2206 Fine to very fine silty oil-saturated sand. 3 MPF. 2207 Very fine silty oil-saturated sand. 5 MPF. 2208 Like preceding. 6 MPF. 2209 Hard fine siltstone with clay matrix, impermeable, dip about 3 degrees. 7 MPF. 2210 Like preceding. 5 MPF. 2211 Fine angular to subangular oil-saturated sand with abundant green ~lauconite. 4 MPF. 2212 Fine silty oil-saturated sand with more glauconite than preceding. 3 MPF. 2213 Fine oil-saturated glauconitic sand. 2 MPF. 2214 Like preceding with marine fossils. 4 MPF. 2215 Fine subangular oil-saturated sand. 2216 Like preceding. 3 MPF. 13 2220 - 2250 . . 2217 Very glauconitic fine silty oil-stained sand. 2 MPF. 2218 Fine glauconi tic oil-saturated sand. 2 MPF. 2219 Like preceding. 2 MPF. 2220 Like preceding. 2 MPF. Core No.8. Recovered 30 feet. 2222 Mostly fine sand, many quartz granules, much glauconite, very fossiliferous. 1 MPF. 2223 Very glauconitic fine angular sand with silty matrix, oil-saturated. 1 MPF. 2224 Like preceding. 1 MPF. 2225 Lide preceding, extremely glauconitic. 1 MPF. 2226 Like preceding. 1 MPF. 2227 Like preceding. 1 MPF. 2228 Like preceding. 1 MPF. 2229 Fine to coarse, very glauconitic, fossiliferous sand. Oil-saturated. 1 MPF. 2230 Fine to coarse sand with granules of quartz and green shale, much glauconite, oil-saturated. 1 MPF. 2231 Fine oil-saturated sand. ']here are no bedding planes that indicate the dip. 2 MPF. 2232 Like preceding. 4 MPF. 2233 Fine silty hard light oil-saturated sand. 2 MPF. 2234 Fine oil-saturated sand. 4 MPF. 2235 Like preceding. 2 MPF. 2236 Very silty fine hard oil-saturated sand. 2 MPF. 2237 Like preceding. 4 MPF. 2238 Fine hard tight silty oil-saturated sand, dip near 3 degrees. 2 MPF. 14 2250 - 2255 2255 - 2285 . . 2239 Like preceding. 2 MPF. 2240 Like preceding. 2 MPF. 2241 Fine oil-saturated sand. 3 MPF. 2242 Fine oil-saturated silty sand. 2 MPF. 2243 Like preceding without fossils. 3 MPF. 2244 Like preceding without fossils. 3 MPF. 2245 Like preceding. 2 MPF. 2246 Like preceding. 3 MPF. 2247 Like preceding. 2 MPF. 2248 Fine hard silty fossiliferous sand. 2 MPF. 2249 Like preceding. 2 MPF. 2250 Like preceding. 3 MPF. Drillstem test 2096 to 2250; 950 ft. mud and some oil in drill pipe. Drilled. Medium to fine grained hard angular sand and miscellaneous cavings. Core No.9. Recovered 30 feet. 2255 Fine angular oil-saturated sand with abundant glauconite and shell fragments. 2256 Fine hard silty poorly oil-saturated tight sand. 6 MPF. 2257 Fine hard silty oil-saturated sand, very tight, fossil fragments. 4 MPF. 2258 Like preceding. 3 MPF. 2259 Very silty fine hard poorly saturated sand, fossil fragments. 3 MPF. 2260 Like preceding. 2 MPF. 2261 Like preceding. 2 MPF. 2262 Very finely sandy siltstone with a white clay matrix, few fossil fragments, no porosity. 3 MPF. 2263 Fine silty sand with greenish gray silty clay 15 . . pebbles from weathered basement, much glauconite fossil fragments, moderate oil saturation. 3 MPF. 2264 Sand as above and argillite as below, 4 MPF. Base of Triassic and top of argillite. 2265 Light gray indurated laminated talk-like argillite. Light color is result of weathering. Dip 18 degrees. 2265 Very hard gray-black argillite. Dip 20 degrees. 2266 Like preceding. 2267 Like preceding, dip 20 degrees. 2268 Very hard, very miceceous argillite, dip 20 degrees. 2269 Like preceding, dip 32 degrees(?). 2270 Like preceding, dip 25 degrees. 2271 Like preceding, a vein filling hades. 2 degrees. 2272 Like preceding with secondary quartz. 2273 Gray-black argillite. 2274 Same, dip 21 degrees. 2275 Same, dip 16 degrees. 2276 Same, dip indefinite. 2278 Same, dip 20 degrees. 2280 Same, dip 25 degrees. 2282 Same. 2283 Same, total depth. (Ø'#¿ 16 ./ .-/,;~~ // /\ " ?¿ ~ ~... . . DRILLING AND COMPLETION REPORT SOUTH BARROW GAS WELL #12 Naval Petroleum Reserve No. 4 Barrow, Alaska 99723 28 February 1975 ~)ø~>C? r7~'L- ~rriarn Jac~ ~.~ ~ ~ Drilling Superintendent ~~&v~~;;. E. LCDR, CEC, USN Officer in Charge ~,""",~ _-~. OF Ai~'~ ~ ~ft,... ... ..;o:'f."~... ,."....Y:.. .e.., ;"t." . e,. . I '*l49JJt .., *' ~._.......e·············l ~........ ,............... ~ ~ ~'... RICHARD V. SHAfER .~Il: J '#~~.. No. 3640-E o.~h ..'h"..... ~"'" .,\.t?I 1......" ~...\\. ~-." \,«~~,~--..- T A B L E 0 F C 0 N T E N T S 1. INTRODUCTION AND SCOPE 2. WELL DATA 2.1 Data Summary 2.2 Wellhead Diagram 2.3 Wellbore Completion Profile 2.4 Drilling Equipment Layout 2.5 Location Map 3. DRILLING JOURNAL 4. DRILLING CREW 5. PERMITS AND REPORTS 5.1 Department of Interior Permit Application 5.2 State of Alaska Permit Application 5.3 Department of Interior Completion Report 5.4 State of Alaska Completion Report 6. LOGS AND TESTS 6.1 Production Test 7. GEOLOGICAL CONSIDERATIONS 7.1 Lithology I N T R 0 D U C T 1 0 N A N D S C 0 P E This report describes work done in drilling and completion of Well Number 12 in the South Barrow Field, This exploratory step -out well was drilled under the supervision of the officer in Charge, Naval Petroleum Reserve No. 4, by Pacific Architects and Engineers, Inc., for the Director, Naval Petroleum and Oil Shale Reserves to test an anticlinal nose which appears to be similar to the now -productive structure in the South Barrow Field. The purpose of this well was to seek additional natural gas reserves in the Barrow area and test for the possibility of other hydrocarbons. The South Barrow Gas Sand (Jurassic) was found to be marginally productive. The composition of the gas is somewhat different than in the established portions of the field, and surprisingly high concentrations of helium were measured in the gas. A deeper sand zone (Triassic) was found to contain oil, but productive potential was considered sub- marginal, and the oil zone was plugged back. The well was completed as a gas producer. . . 2. W ELL D A T A 2.1 DATA SUMMARY FIELD: South Barrow Gas Field PROPERTY: Naval Petroleum Reserve No. 4 (U. S. Government) WELL NO: Gas Well No. 12 LOCATION: 22.8' R17W, State x = FSL, 1754.9' FEL Section 23, T22N, Umiat Principal Meridian. [(Alaska Plane Coordinate System: 695,850. y = 6,305,300 (zone 6)] ELEVATION: 26 ft. (approximate) ground level above sea level. DATUM: All depth measurements are referenced to kelly bushing top (KB). KB is 12 ft. above ground level. DATE OF REPORT: 28 February 1975 DRILLED WITH: Navy owned Cardwell Model H drilling rig No. 3 DATE COMMENCED DRILLING: 10 March 1974 DATE OF COMPLETION: 4 May 1974 PRODUCTION TEST DATA: Calculated absolute open flow potential = 360 + MCF/day. (See details in section 7.3 of this report. ) PRODUCING FORMATION: South Barrow Gas Sand. TOTAL DEPTH: 2285', plugged back to 2088' CASING AND CEMENTING PROGRAM: 24-in. OD Conductor Pipe, 1 joint, cemented at 20 ft. KB 16-in. OD Casing, 4 joints, N-80, 75 lb/ft. with 345 sacks permafrost cement. 10 % -in OD Casing, 29 Joints P-5l, 51 lb/ft range 3, buttress T & C. Cemented at 1067 ft KB with 950 sacks permafrost cement . . 7-in. flush sacks class OD Casing, 48 joints, 23 Ib/ft, range 3 joint. Cemented at 1884 ft. KB with 340 permafrost cement followed by 278 sacks "g" cement. LINER: 51¡i-in. Blank Liner, Security flush joint, 1 joint, J-55, 20 Ib/ft., range 3. 5I/2-in. Slotted Liner, 2062 ft. KB, Security flush joint, J-55, 20 Ib/ft, range 3. Bottom joint orange peeled and spaded. TUBING: 27/s-in. EUE tubing, 65 sub and one 4-ft. sub, range 2, 8 Rnd T & C. at 2053 ft. KB. joints + one 12-ft. J-55, 6.5 Ib/ft, Tubing bottom WELL HEAD: Rucker-Shaffer Wellhead Assembly 10~4 X 7 X 2~s-in, Drawing No. SK-N-083 (See section 2.2 of this report). MASTER VALVE: WKM Steel Valve 2~s EUE 8 Rnd. Female thread SURVEYS: Schlumberger Dual Induction Laterolog Proximity Log - Microlog Compensated Neutron-Formation Density Compensated Formation Density (Gamma-Gamma) Borehole Compensated Sonic Borehole Geometry Log Four-Arm High Resolution Continuous Dipmeter Cement Bond Log Saraband Halliburton Successful drill stem tests were made at 1885-1985 and 2100-2250. Core Lab Core analysis was provided on various samples from 1966 to 2060 ft. KB Reservoir fluid analysis was made on a sample from the oil formation. (Samples were taken by North Star Engineering) Petro-Tech Mud Log Bureau of Mines Gas analysis 2 . 2.W ELL II E A D 2" x 10" Double Extra Strong 2" Nordstrom Valve, Fig. 2344 2" Bull Plug, Extra Strong RUCKER-SHAFFER Wellhead Assembly 1034 x 7" x iI's" Dwg. SK-N-083 S cal e : 1"::: I' 0" \Zirk Fitting = \ (~( Swage Extra Heavy i~" OD \ _I EUE 8 Rd x 2" LP ( I I \ I I I' _ \1\S~ j ~ WKM Steel Valve #297592 ~, --¡----- ·c~, I " ~ ~ ¡ I i 6 - 5;0 00 ) D I A \ 1 \, l F\ t\ --1 ¡ 3þOO , I \ ) " 10 - I ~ \ ) ( " / / I f t \r A M 2%11 OD EUE 8 Rd 2" x 10 " Double Extra Strong r- 2" Nordstrom j=\. Valve, Fig. 2344 I r- 2" Nordstrom J=\. Valve, Fig. 2344 I 2" x 10" Double Extra Strong 100/4" 49.5-lb. Casing 7" 23-lb. Extreme Line Casing 2%" Tubing W ELL H E A D SOUTH BARROW WELL NO. 12 2.3 tv ELL B.R E ----.---- Depths, KB (feet) ~\~\ ~;., ::. .:: :: {~/' .:.: :(:i· 20 .;;" 2211 hole_ 160 170 . Ii :. ~.. nT .; ~:: ~. 14%11 hole--- ß. 1Jl " ... ... 1067 .';,.:; =:0.: ~ ~::; 1070 9 %" ho I e .. 1861 1869 1884 2053 2062 2088 2190 :~. ., .~ -: .. .. .:.;. COMPLE'I'IO. tf.:i =? ::~f ~'1 ~ ':' . .'. ., :;"..: ÎI;: .0. .:.., ::' ::~ . . . . . .:~!ú.. :.::~ .:,~~ ...::%%' ....~ .:.:.;::::< ..~ .~:~ .,~ :; "-" ~~ .~ iIoø- j~~~/H~}(~ T{JJr!! ~ -:: ::: 2255 7%" core hole 2287 (no scale) r,.!!_' Liner ?---- Brown -':: Blank J-55, - PRO F I L E 24" Conductor, I j t. 16" 00 Casing, 4 jts, N-80, 75fflf.t Range 3 8-Rnd T & C 10]4" 00 Casing, 29 j-~s, P-51, 51lflft Range 3, Buttress T & C 2 7/s" E U E Tub i n g, 65 j t s, J - 5 5, 6. 5 # I ft Range 2, 8 Rnd, T & C 7" Extreme Line Casing, 48 jts, Ex-~reme Line, 23f/ft, Range 3, flush joint l::1anger S lips Liner Hanger 5%" Liner, Securit~ 20fflft. Range 3 Flush ,Joint, Slotted 5%" Liner, Security Flush Joint J-5S, 20#/ft, Range 3 Cement Plug ~'JELL 12 PROFILE South Barrow Field Naval Petroleum Reserve No. 1 Alaska . 2 . 4 D R ILL I N G E QUI P MEN T LAY 0 U T Geologist Wanigan ~- Pipe Racks T , , -1- __________I ~-- \. / ~ ( " ,. I I I 1 ..!.. Oilfield \ Warehouse ~ I ,J I I I ì ~ SCALE: I" = 5 0 ft. . ,""-- Mud I / I\D Tank Wanigan Pump Wanigan -~ - L 7- ~Boiler Wanigan Water Storage Wanigan ~ C-250 Pump & Quads '- Cardwell Rig HOWCO Unit ---------- Shop ______ 50/75 ~W Generator _______ Wanlgan ~ Mess Hall / r:/ /,r- Crew C~ange ,/' Wanlgan / Dry Head ~ ~ NAVAL PETROLEUM RESERVE NO. 4 SOUTH BARROW FIELD 6 5 BARROW, ALASKA WELL 12 LOCATION : 63t360 I\J êL.s ~. 7 8 0A' L. 4(;'0 0...., ~.oon t"' ~ 0 /8 /7 n ::Þ /6 /4 /3 /7 t-3 o Avak Test Vfe II lo H South Barrow 0 2/ 22 Well No 12 24 /9 2/ Z /9 20 22.8' N of S line 1754.9'Wof Eline 22 Sect. 23--0 :s: ::Þ. 29 28 27 26 25 30 29 28 27 I'IJ 30 3/ 32 33 34 35 ~~ 36 3/ 32 33 ~~ Lag A ~~ T22N T2/N 6 5 4 3 2 / 6 5 4 3 08 MAR 74 09 MAR 74 10 MAR 74 11 MAR 74 12 MAR 74 13 MAR 74 14 MAR 74 15 MAR 74 16 MAR 74 17 MAR 74 18 MAR 74 19 MAR 74 20 MAR 74 . . 3. D R ILL I N G J 0 URN A L Moved equipment from South Barrow No. 11 to South Barrow No. 12. Started rigging up. Continued rigging up. Continued rigging up. Mixed CaC12 solution. Spudded at 2130 hour's. Drilled 14% inch hole from 31 feet to 44 feet, with Bit No.1. Drilled 14%" hole 44 feet to 208 feet with Bit No. l. Opened hole from 14%" to 22" with rerun PHO. Ran 4 joints (160') of 16" casing. Cemented same. Cement in place at 1000 hours. Waited on cement. Waited on cement from 0001 hours to 1600 hours. From 1600 hours to 2000 hours drilled float collars, cement and shoe. From 2000 hours to 2400 hours, drilled 14 %." hole from 208' to 315' with Bit No.1. From 0001 hours to 0200 hours, drill~d 14 %'J hole from 315' to 352' with Bit No.1. From 0200 to 0400 hours, tripped for bit. From 0400 to 2400, drilled 14 %" hole from 332' to 865' with Bit No.2. From 0001 to 1030 hours, drilled 14 %" hole from 865' to 1070' with Bit No.2. From 1030 to 1630, conditioned hole for logs. During 1630 to 2100, pulled out of hole. From 2100 to 2400 hours, ran Schlumberger logs. Logged from 0001 to 0400 hours. From 0400 to 1200 hours conditioned hole for casing. From 1200 to 2350 hours ran and cemented casing. From 2350 to 2400, squeezed. From 0001 to 0145 hours, squeezed cement. Had 400 PSI. Bumped plus with 1,000 PSI. Cement in place at 0200. Waited on cement from 0200 to 2400 hours. Waited on cement. Nippled up. Ran cement bond log. Changed liners in pump. Waited on cement from 0001 to 0400 hours. From 0400 to 0430 tested blowout preventers. Drilled out float collar (cement green). From 0430 to 2300 waited on cement. Drilled 9 %" hole from 2300 to 2400, 1070' to 1134' with bit No.3. From 0001 to 2400, drilled 9 %" hole from 1134' to 1785' with bit No.3. 21 MAR 74 22 MAR 74 23 MAR 74 24 MAR 74 25 MAR 74 26 MAR 74 27 MAR 74 28 MAR 74 . ty/V . From 0001 to 0330, repaired mud lines. From 0330 to 0630, drilled 9%" hole from 1785' to 1840' with bit No.3. From 0630 to 1200, tripped for bit. 1200 to 1800 drilled 9~" hole from 1849' to 1965' with bit No.4. From 1800 to 2000 conditioned hole to core. From 2000 to 2400 pulled out for core barrel. From 0001 to 0200, trip~ed in with 30' Christiansen core barrel and Navy owned 718" x 3 V2" core head. Core barrel plugged. From 0200 to 1300, tripped to unplug core barrel. From 1300 to 1500, cut 20' core. From 1500 to 1800, pulled core No.1. Made full recovery. From 1800 to 2400, picked up Halliburton test tool. From 0001 to 0200, tripped in with drill stem test (DST). From 0200 to 1200 tested 1885' to 1985'. From 1200 to 2000, pulled DST No.1. Went in hole with core barrel from 2000 to 2230. 2230 to 2400, core No.2 from 1985' to 2017'. Pulled core No. 2 from 0001 to 0300. Made full recovery. From 0300 to 0900, tripped in and conditioned hole. From 0900 to 1100 made core No.3 from 2017' to 2046'. Pulled core No. 3 from 1100 to 1400. Made full recovery. Tripped in with core barrel from 1400 to 1600. From 1600 to 1800 cored No.4 from 2046' to 2076'. From 2000 to 2400, pulled core No.4. Made full recovery. From 0001 to 0300, tripped in with core barrel. Conditioned hole from 0300 to 0700 core No.5 from 2076' to 2101'. From 0700 to 1100, pulled core No.5. Made full recovery. From 1100 to 1300 picked up test tools for DST #2. From 1300 to 1700 tripped in with DST #2. Packer failed. From 1700 to 2300, pulled test tools. Packer set at 1985'. Tripped in with DST #3. Tripped in from 0001 to 0300 with DST #3. Packer failed. From 0300 to 0900 pulled DST #3. Packer set at 1946'.. Traveling blocks locked. From 0900 to 1600, changed trav- eling blocks. From 1600 to 1830, tripped in with Bit No.5. From 1830 to 2400, reamed 7 %" hole to 9 %", from 1986' to 2077' . From 0001 to 0100, reamed 7 %" to 9 %", interval 2077' to 2101'. From 0100 to 0900, drilled and circulated for samples 2101' to 2163'. From 0900 to 1300, conditioned hole, pulled bit No.5. From 1300 to 1500, tripped in with core barrel. From 1500 to 2230 cut core No.6 from 2163' to 2192'. From 2230 to 2400, pulled core No.6. From 0001 to 0200, pulled core No.6. Made full recovery. From 0200 to 0430, tripped in with core barrel. From 0430 to 0830, cut core No.7 from 2192' to 2220'. From 0830 to 1200, pulled core No.7. Made full recovery. 29 MAR 74 30 MAR 74 31 MAR 74 01 APR 74 02 APR 74 03 APR 74 04 APR 74 05 APR 74 06 APR 74 07 APR 74 08 APR 74 09 APR 74 10 APR 74 . . From 1200 to 1400, changed bearing in core barrel. From 1400 to 1800, tripped in with core barrel. From 1800 to 1930, cut core #8 from 2220' to 2250'. From 1930 to 2400, pulled core No.8. Made 27' recovery. From 0001 to 0300, picked up, tripped in with DST #4. From 0300 to 1200, tested interval 2100' to 2250'. From 1200 to 1400, reversed out test. From 1400 to 1800 pulled DST #4. From 1800 to 2100, tripped in with bit #5. From 0001 to 0200, reamed 7 % II to 9 % II interval 2217' to 2250'. Drilled 2250' to 2255'. From 0200 to 0600, conditioned hole, tripped out with Bit #5. From 0600 to 1000, tripped in with core barrel. From 1000 to 1600 cut core #9 interval 2255' to 2285'. From 1600 to 2200, pulled core #9. Made full recovery. From 2200 to 2300, laid down core barrel. From 2300 to 2400, ran Schlumberger logs. From 0001 to 1400, ran Schlumberger logs. From 1400 to 2400, laid down 7 % II drill collars. Reduced crew to one day tour of 9 men and 2 men on night watch. Performed miscellaneous maintenance. Performed miscellaneous maintenance. Performed miscellaneous maintenance. Fabricated lubricator for swab. From 1200 to 1300, ran 6" rerun bit to shoe. Circulated at 1070'. From 1300 to 1800 circulated. From 0600 to 1800, hooked up test tanks. From 0600 to 1800, tripped to bottom, cleaned out 3' fill. Conditioned hole. Tripped out. Picked up test tool; stood in derrick. From 0600 to 1800, laid down drill pipe and kelly. Changed rams in blowout preventer. From 0600 to 1200, picked up test tool and drill collars. From 1200 to 1800, picked up 2'la EUE tubing. From 0600 to 1300, ran tubing to 1,000 feet. Circulated. From 1300 to 1800, tripped out and ran packer. Interval tested 2192' to 2288'. Swabbed from 0600 to 1600. From 1600 to 1800 ran Star Eng. testing equipment. From 0600 to 1800, Star Engineering did testing and sampling. 11 APR 74 12 APR 74 13 APR 74 14 APR 74 15 APR 74 16 APR 74 17 APR 74 18 APR 74 19 APR 74 20 APR 74 21 APR 74 22 APR 74 23 APR 74 24 APR 74 25 APR 74 26 APR 74 27 APR 74 . From 0600 to 1600 to 1800 . 1600, Star Engineering did pulled packer loose. sampling. From From 0600 to 0800 pulled test tools. From 0800 to 1330, tripped in to plug. From 1330 to 1600, plugged back from 2190' to 2070' with 30 sacks of Permafrost and 30 sacks of Class G. Cement in place at 1530. From 0600 to 1800, waited on cement. Tripped for bit to polish plug. From 0600 to 1800, found top of cement at 2032'. Drilled out to 2075'. Tripped out and picked up DST tools. From 0600 to 0700, tripped in and set packer. Swabbed from 0700 to 1200. From 1230 to 1330, flared well. From 1330 to 1530, shut in. From 1530 to 1600, flared well. From 0600 to 0930, flared well through Shaffer bean pressure after 15 hours: shut in 895 PSI, decreased to 340 through o/6~" choke in 1 hr. 15 min. Increased with %~" choke to 380 in 55 minutes. Pulled DST tools, laid down drill collars and test tools. From 0600 to 0800, loaded out test tools. From 0800 to 1200, tripped in with bit. Cleaned out to 2088'. From 1200 to 1800, circulated. Picked up 7~" drill collar. From 0600 to 1800, mixed CaClz. Displaced drilling mud. From 1600 to 1800, mixed CaClz. Circulated. Pulled tubing. Ran DST tools in hole. Packer set at 2014 DST #7. From 0600 to 0900, swabbed well in. From 0900 to 1800, flared well intermittently. Tested flow rate. From 0600 to 1400, tested. From 1400 to 1800, pulled packer loose. From 0600 to 1800, worked packer through tight hole. From 0600 to 1800, finished tripping out DST #7. Mixed CaClz. Tripped in with 9%" bit. Cleaned out fill to 1375'. From 0600 to 1800, cleaned out fill from 1760' to 2060'. From 0600 to 1200, cleaned out fill to 2075'. From 1200 to 2000, ran 48 joints (1884') of 7" 23# Range 3 casing. Cemented with 340 sacks of Permafrost and 278 sacks of Class G cement. Cemented in place at 2215. From 0600 to 1800, waited on cement. 28 APR 74 29 APR 74 30 APR 74 01 MAY 74 02 MAY 74 03 MAY 74 04 MAY 74 05 MAY 74 06 MAY 74 . . From 0600 to 1800, cut off 7" casing. Nippled up. From 0600 to 1800, finished nippling up. Cleaned out cement to 1830'. From 0600 to 1800, drilled out cement and shoe. Ran bit to 2088'. No cement below packer shoe. Pulled out to shoe. From 0600 to 1800, ran bit to 2088'. Pulled out and picked up 51/2" liner. liner at 2062'. Checked for fill. Ran in and hllng From 0600 to 1100, ran 65 joints (2053') of 2'la EUE 8 rnd. Range 2 tubing. From 1100 to 1800, rigged down blowout preventer equipment. Rigged up to swab. From 0600 to 1200, pumped 60 barrels CaC12 solution into formation. From 1200 to 1800, swabbed well. From 0600 to 0800, swabbed well. From 0800 to 1200, flared well. From 1200 to 1800, rigged down. Rigged down with 6 man rig crew. Continued to rig down. Moved equipment to Gas Well No. 5 for workover. 07 MAY 74 to Worked on Gas Well No. 5 13 MAY 74 13 MAY 74 Continued to rig down and move equipment. 14 MAY 74 Continued to rig down. 15 MAY 74 Skidded rig to South Barrow No. 13. . . 4. DRILLING CREW AS OF 27 MARCH 1974 SUPERINTENDENT TOOL PUSHERS DRILLER DERRICKMAN MOTORMAN FLOORMAN FLOORMAN ROUSTABOUT ROUSTABOUT MECHANIC OPERATOR ARDCO DRIVER Rig Area Support FOREMAN OPERATOR CARPENTER OILER ~Dgi8tia8 Support MECHANIC MECHANIC OPERATOR ROUSTABOUT Camp Support COOK BULLCOOK KITCHEN HELPER WAREHOUSEMAN CLERK TIMEKEEPER Crew Bill Jacoby W. B. Barnett F. M. Roberts Morning Tour John Jacoby Johnny Maresh Vern Conway Douglas Edwardsen James Donham Joshua Nashaknik James Aiken Tom Welborn Walt Rasmussen Jerry Russell Cliff Johnson Larry Kaleak Mac Davis Lloyd Ipalook Paul Reiman Al Bales Andy Kemak John Zellar Charles Durkow Caleb Nayukok Eunice Aishanna Ken Siebert Lula Ahsoak Maynard Moline 0600 to 1800 1800 to 0600 Evening Tour Jack Crabtree Jodie Tyler Frank Parchman Walt Ahmoagak William Reagan Joe panigeo, Jr. Steve Hopson Jerry Fries Charlie Edwardsen Elmo Unrein ~t~;~T~¡:;:ïSH 11Ál!:~a 17. NO. OF c4CBES:ASSIG;NBD TO TBIS"WII.LL ' ~/A . Form. 9-331 C (May 1963) SUBMIT IN TRIPLICATE'" (Other instructions on reverse side) UNITED STATES DEPARTMENT OF THE INTERIOR GEOLOGICAL SURVEY APPLlCA TION fOR PERMIT TO DRill, DEEPEN, OR PLUG BACK DEEPEN 0 PLUG BACK 0 1a. TYPE OF WORK DRILL I[] b. TYPE OF WELL OIL 0 WELL 2. NAME OF OPERATOR IX] MULTIPLE ZONE OTHER SINGLII ZONE GAS IVl WELL ~ Director, Naval Petroleum and Oil Shale Reserves 3. ADDBESS OF OPEBATOR Rm. 550, Crystal Plaza #6, Washington, DC 20360* 4. LOCATION OF WELL (Report location clearly and in accordance with any State requirements.'") A t surface Alaska State Coord. System Zone 6: 6,305,300 (N); tt h95~850 (E); Umiat Prime Meridian. Approx. 71014'16.5"N proposeôrprou. zone same as surface) 156020'15.0"W 14. DISTANCIII IN MILES AND DIRECTION FROM NEAREST TOWN OR POST OFFICE'" 10.6 mi IIi. DISTANCE FBOM PROPOSED· LOCATION TO NEAREST PBOPERTY OR LEASE LINE. FT. N/ A (Also to nearest drlg. unit line, if any) 18. DISTANCE FROM PROPOSED LOCATION. ;~ ;:~SioR~~~LT~~L~C;;, ~~PLETED, 5. 9 mi 16. NO. OF ACRES IN LllASIII N/A . 11100.1-SB12 Ser:l0~ Form approved. Budget Bureau No. 42-RI425. i ã. LEASE DESIGNATION AND SIIIRIAL NO. I Naval Pe!troleum=R.èserve 114 6' n'}J';"DIAN, ALLO~TEE OB TRmE NAMIII N/A 7; Ui'(I'J!, AGBIIIEMIIINT NAME o '\N ¡fA'," S: F~M OR :r;EASE ,.NAME NtA-: 9" WIIIL~ NO.' '125 ; 10. ~IB!<D ANI! POO' ';. OB')V'ILDCAT Wildcat. " ." n. SEé;, 1'., B.. M....OR BLK.·. ARP. SURVEY Ol~' AREAl ~, .... -< 'ßëet .~6 ,;r22N i; R17W _..~ ~, 20. ROTAltY"OR,CÃÏlLE 'J'ÖOLS RotárY:;.' 19. PROPOSIID DEPTH 2,350 ft 21. ELEVATIONS (Show whether DF, RT. GR. etc.) Ground: Approx. 12 ft MSL: KB ~ 16 ft MSL 23. PROPOSED CASING AND CEMENTING PROGRAM SIZE OF HOLE WEIGHT PER FOOT SIiI'rrING DEPTH SIZE OF CASING 14 3/4 in 9 5/8 in Open hole 10 3/4 7 from approx 1.·....22;,.:;kP.:~... PRO::'D"';T.. E....WOB~ -wvILL START'" :;, :09 MARl!f qUANTITiOF~~"MENT;: 51 Ib 23 Ib 1,750 ft wi-:h 1. 260 ft 1,650 ft 5-in O.D. 7 5Ð~s5ê '43[61; ¡ pe:::-f. .1~Ìlér .~. (thêbi·etld:;rl) ( tfhãh'retj:.c'B.1) in in 1,650 to "' ..~ The Director, Naval Petroleum and Oil Shale Reserves intends to.&r:iiia ~èfl; in,~,S;~t. 26, T22N, R17W, Umiat PM. The contractor is Pacific Architects add7Engí.n~erS~);L:Ç1c.~.LÒs Angeles, Calif. The well is being drilled to test the South Ba~TQw~aS ~a~~~in~~'$tructure about 6 mi from the presently producing structure. It will be d~~îl~~ t~r6ùgh ¥q~;South Barrow Gas Sand to test deeper horizons for possible productivity .:_~;q gë:!s )tS f~U:p~ in the South Barrow Gas Sand, but no deeper pay is found, deeper ZQþë~~~ll~~~so~ted by cement plugs and the well completed as shown above. If deeper PFaduêtion;- J+.s·) fO\i11'd; a revised program will be submitted. The well is being drilled t(); aug~entthe<r~seFÿes of gas available to meet the needs of government facilities in thê' a¡-èa,'ancl: tl1~eömmunity of Barrow. .: '. ". -'- . *Direct inquiries to: Officer in Charge, Naval Petroleum Reserve No. 4, B~rrow~ 'ÅK 99723 IN ABOVE SPACE DESCRIBE PROPOSED PROGRAM: If proposal is to deepen or plug back. give data on present p~ucl1ve zone ·and proposed néW productive zone. If proposal is to drill or deepen directionaily, give pertinent data on subsurface locations and measu~ aÍ1d1rlIe v#r;ticàJ 4épt!îs~Giye blowout preventer PR' . \ . 24. I . ): SIGNED . . S DR, CEC, USN TITLE Officer in Charge (This space for Federal or State office use) PERMIT NO. APPBOV AL DATE APPROVED RY CONDITIONS OF APPROVAL, IF ANY: TITLE . ~UnM11 jA 10nu..1.d. (OthfOr Instrur.Uons on reverse side) Ponn \0 - 401 RJ:V. 1 -1-71 STATE OF ALASKA Oil AND GAS CONSERVATION .cOMMITTEE" I. PERMIT TO DRILL OR DEEPEN 8. LEASE D1!2SIGNATION AND Sl!:IUAL NO. Naval Petroleum Reserve #4 1&. Typa or "'oaK DRILL 00 DEEPEN 0 7. JF INDIAN. ALLO'M'EE OR TRIBE NAME N/A II. TYPII 01' ",aLL OIL 0 OU IV'1 "'IILL WIiLL ~ 2. NAME OF OPERATOR Director, Naval Petroleum and Oil Shale Reserves 3. ADDRESS c:Jf' OPERATOR OTKa. 81NGLII 0 ZONII Mtll.TII'I.1I 0 ZONE 8. UNIT FARM OR LEASE NAME N/A 9. WELL NO. 12 Rm 550, Crystal Plaza #6, Washington, DC 20360* ~. LOCATION OF WELL At surface Alaska State Coord. System, Zone 6: 6,305,300N; 695,850E; Umiat At proposed prod. zOne Principal Meridian Same as surface 13. DISTANCE IN MILES AND DIRECTION FROM NEAREST TOWN OR POST OFFICE· 10. nELc AND POOL. OR WILDCAT Wildcat \1. SEC.. T.. R.. M., !BOTTOM HOLE OBJECTIVE) Sect. 26, T22N, R17W 1Z. 10.6 mi 14. BOND INFORMATION: TYPE N/ A N/A N/A AmoQnt 17. NO. ACRES ASSIGNED TO THiS WELL N/A Surety and/or No. 15. DISTANCE FROM PROPOSED· LOCATION TO NEAREST PROPERTY OR LEASE LINE, 1"1'. (Also to nearest drig, unit, if any) 18. DISTANCE FROM PROPOSED LOCATION· TO NEAREST WELL DRILLING. COMPLETED. OR APPLIED FOR. 1"1'. 18. NO. OF ACRES IN LEASE 19. PROPOSED DEPTH 20. ROTARY OR CABLE ·TOOLS 5.9 mi 2,350 ft Rotary 21. ELEVATIONS (Show whether DF. RT. GR. etc.' Ground: approx. 12 ft MSL; KB ~ 16 ft MSL 22. APPROX. DATE WORK WILL START· 09 MAR 74 23. PROPOSED CASING AND CEMENTING PROGRAM 11ZE OF HOLE .L4 3/4 in 9 5/8 in Open hole SIZE OF CASING WEIGHT PER FOOT 10 3/4 in ~ 51 Ib 7 in 23 lb ~rom approx 1.650 to GUDE SJ:rI'ING DEPTH N-80 1,260 ft J-55 1,650ft 1.7)0 ft wIth 5-in perf. 750 sx 436 sx liner. quantity of Cement (theoretical) . (theoretical) The Director, Naval Petroleum and Oil Shale Reserves intends to drill a well in Sect. 26, T22N, R17W, Umiat PM. The contractor is Pacific Architects and Engineers, Inc., Los Angeles, Calif. The well is being drilled to test the South Barrow Gas Sand in a structure about 6 mi from the presently producing structure. It will be drilled through the South Barrow Gas Sand to test deeper horizons for possible productivity. If gas is found in the South Barrow Gas Sand, but no deeper pay is found, deeper zones will be iso- lated by cement plugs and the well completed as shown above. If deeper production is found, a revised program will be submitted. The well is being drilled to augment the reserves of gas available to meet the needs of government facilities in the area, and the community of Barrow. (Continued next page) IN ABOVE SPACE D1!BCIUBI: PROPOSED PROGRAM: If __1 Is to deepen C1ve data on p~sent productive ZOM AJ:1d proposed ne~-..~. .. JL~t<> .. _ I IJ IA!. arlll. or deepen aln!ctJona!lY. 8tve per\U1ent. data· on· sUbsurface J.QcàtiOns and mea__d and tl'ue . v iea de. b_ t preve!.1ter pro~am. 24.1 her ~..t ~For,~~~¿:n;~N DA- 24 February 1974 Officer in Charge S!GNrD ~l..uJ:\."" TI'noJ: (This spac:e for State office use) CONDmONS OF APPROVAL, IF ANY: SAMPLES AND CORE CHIPS RmQVIJIIZ) MUD LO'G 0'1'IŒR REQUDU:MENTS: o YES 0 NO 0 YES 0 NO DIRECTIONAL SURVEY REQUDU!:D o YES 0 NO A.P.I. Nt1MJ:IUCAL COD. PI:RM1T NO APPROVAL DATE APPROVED BV 'l'lTLII. *See In......_. On R...... Side J)ATII STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE PERMIT TO DRILL OR DEEPEN (CONTINUED) This application is being filed for information purposes. Please see Director, Naval Petroleum and Oil Shale Reserves letter serial 394 of 27 August 1968. *Direct inquries to: Officer in Charge, Naval Petroleum Reserve No. 4, Barrow, Alaska 99723 WELL COMPLETION OR RECOMPLETION REPORT ANDI LOG * ~ . ~ ' F9I'm 11-330 (Rev. 6-68) UNl::o STATES OEPARTMENT OF THEINTERlpR GEOlOG ICAl SU RVEY Stun,lIT IN QUPLIC. (See other in- structions on reverse side) Form approved. ',-Budget' Buteau No,:4~:"R365.6. ã. ['EASIi1; D!?SIGNA~ION' 4·ND ~EtU.~ NO. NavaliR~t:r()J.eúìU.-Re~'h·.ve #4 6. I! IN~IA:N;,; ALLOTTE~ )R Tip¡jlll' NAME WORK 0 OYER DE}JP- 0 EN N'i'A .~. 7. r¡.~IT'tG,~E~MEl'j'T NAMII NrAg" s. ~~RM'Ol!- LEAS~ NAJ4'II" N/A.o .. 9.:, W·ÈLL~NÍJ. . NEW 0 ,W}JU, la. TYPrOFWELL:~"'u, .....~:~~~uз·~^r.~L~Tlr..··-D·~y·D·· Other b. TYPE OF COMPLETION: .. 2. NAME OF OPERATOR Dir~ctor, Naval Petroleum and Oil Shale Reserves 3. ADDRESS-OI!' ~PER>tTOB""""""" . P[,UG 0 BACK DIFF. 0 RESVR. Other ... Room 550, Crystal Plaza #6, Washington, D. C. 2036Q 4. LOèATION OF WELL (Report location clearlu and in accordance with anll State r~uireme1t8P' At:surface Alaska State Coord. System Zone 6: 6,30~,300 (1\1) 69,5,850 (E)¡ Umiat Prime Meridian. Approx. 7lò14'16.5"N At¡top prod. interval reported below 156020 '15. O"W ''';~ ~2 ~ .. _,. 1~ ,1rUILO A.!iP. po§!-. 011 ,~ILDl::A.T ,s·buth'Bar~oJ3 ~ '._~ F"-,:::: . '-~:~ -.., ," , . l<t.SEC,i'T;;~R.. }[..~9R RL<JCK ANIfS0RVIIY ;'!>R ÅR~À:.;' .-"- .::,.~ ::. ,i ~" "'~ ~ ~eæ~tqn ~6 ,e;' 'Î'22!I¡ !{R17W ;::; Id 114. PIIIRMIT NO. D~TE,. ISSUED 12:. ~u!l.œ"(: ôå :~ I ~liil S'¡ÂTJ!Ì '-"=O=~·',C'_·'=._c'c._-:"cc ._c = c,"=",==c===== ._==,"==~"=_,,..c=.==c... '.' c.cc====cJ>iJi'_A=-c;c===cc" .Jc=,:..--NLA Nã~I~I~gpe~·'~iá:skã ::; l;~D::Pu;:mD Ill:. ::: T;~BUCHmD 11:. ::CO;;L. (Ready to prod.) 18·:;r;¡~;L(DF' RSB, BT, !tTc~~W9.;~LEY11l!~~~D 20. TOTAL DEPTH, JID .. TVD /21. PLUG. BACK T.D., 1IIJI" TVD 122. ::o;u:;~~;: COM PL., :~I ~3. ~~i~t:~~~ ~.?~~~tfLS ..- ·t~.~B~.~...~.. r¡f 2287 2088 N/A, ---. I 248;.'ì.s:ft;;- ;~. .;,,,Q.,.. 24. ~RODUCING INTEBVAL(S), OF THIS COMPLETION~TOP, BOTTOM, NAME (MD AND TVD)-·· . 2'1). :it:~~R~;:;~AL At: total depth Soi~h Barrow Gas Sand - Geological ChaI!-qe 26. ~Yfm ELECTBIC AND OTHER LOGS RUN ~~L, FDC, CNL, BGT, HDT, BHC, CBL, BROX-ML 28. 15 ;~ASING SIZE ~j6" illJl03~" ',$ ¡ II. ~ )7" '.) 29. ;SIZE 5~" .- ~..~ particulars on fife with Office~' '..; ~,~. ,..,., -:-., ," ':""J V ~ Yß$ 2~j-' :.~ ~AS ~~LI¡:; C5'~~~-: .i'Ye':Š:;;î -c ., ~. "'- "~-." . ~:i -:.:.'":Oc -- '~ - ~, '-.. WEIGHT, LB./J'T. CASING RECORD (Report aU øtrintlj "ei ~n ~eU) ~ i[ ~ :~ DIIPTB SET (UD) BOLE SIZE . :: . C}JMENTING REC~~ ~':~ 160' 22" 345 ¡ SX permafrqs·~;:,:~· 1067' l4~4~ ~~O SX PE'rmafr513~~i2.;;.~ 1884' 9%'~ 340 sx Perm., ~7.þ;&xÈ:çiass .. -- 0 ,- 75# 51# 23# N80 P5l -;,¡ :~ S's'~ ~'~ :~. _;: '__ ';""" __J. ._, -'-": .. .._- TOP (UD) LINER RECORD BOTTOM (MD) 39· TUB4~2\~OO!D DEP~B~8~T:;. (!~ 20~.___:,: " SCÕBN (!MD) ª? SACKS cmUENT- SIZII 2ìe" 1884 sJ:ott:eds '.:.:-- 2062 o ~. -' ~-; 31. PIIBJ'ORATION RmCORD (Interval, Bize and numlÞer) 33.- PRODUCTWNc;. ~~ .'.~ §' S ~'>.> þ. D~::::ST ::~~~~~d ·IP.!~I>.U«:"TI~l!)l!I!~()I> ~!,lo.~flf/"f/aa_lit~,_~,,!,,-~~i",f !J.n~ tripe, of pump) ^j~\"tf-!,trf!~{~!'Ò!,qping9'2? ~.;;~ ¡ ~::.: =U I ::~;ft I ~~~ ':::.,., " ..ftJJ~~n~~~~·) 34. DI~SITroN"OJ'-QAlrlSJ:I"ä;,jjir4-rOrrvø1;1ímn6ã;øt'ë:r--'m I T~~b~~~:r:, r= 35. LIs(r OF 4TTACHMBNTS = . ~. ~ ~~ ~ ~ ~ ~. ~ ~ ~"j=: 36. I ~.... reby certify that the fa. regoing an. d~ttaCh ¡;:tiOD i8 CO~lete a~.~ cor.,. 3et,' ga~ ~- îtermined from all ..~..~v:a...;f~~ ~..~.'. é-Èo.C....01:...;d. ~..~ -:.:~.!.. .~.'.;. '.:."..._ê SIGNE;-7~ ,~, · f- ~';::~~~'r·" ineiarqe ~1~~'1l.&;~~-3iß~i~:-~ R. V. Shafer. LCDR. C , USN -~ , 't .~ .~ -:::.~ ~ ... ,~ 5.. :3;:... , .~, = -""'" -r.V .""''' __ =_., ;...¡,. *(See Instructions and Spaces for Additional Data ôn Reverse Side) *Multipoint back pressure test. 32. ' ÃØm.; SHOT, FRACTURÉ; ':òt1\.lEÑT;SQ9EZE,1SETC; . ._~,:" ; ".. ;~~ -" i-_ ."~"" ,._c-' >.... :-, 0.-, D»iTB ÙfTmlt~À} (~D) UIOU~;~¡f~ ~fi'æo!'~ATBfR¡ji' ~~tj> c';' ,-,. -¡- '.~' '.':::¡ Form P-7 . . SUBMIT IN DUPLICATE" STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE {S~E' other in- structions on reverse side J WELL COMPLETION OR RECOMPLETION REPORT AND LOG * 011. 0 WELL DEEP- 0 £s la. TYPE OF WELL: GAS IV1 WELL tKJ DRY 0 Other b. TYPE OF COMPLETION: :-iEW 0 wonK 0 WELL OYF:R DIFF. 0 ßESVR. PLUG 0 BACK Other 2. NAME OF OPERATOR Director, Naval Petroleum and Oil Shale Reserves 3. AnDRESS OF OPERATOR Room 550, Crystal Plaza #6, Washington, D. C. 20360 4. !,OCATION OF WELL (Report location clearllf and in accordance with an / State requirements)" At surface Alaska State Coord. System Zone 6: 6,305,300 (N) ¡ 695,850 (E)¡ umiat Prime Meridian. Approx 7lOl4'16.5"N At top prod. Interval reported below 156°20 '15. O"W A t total depth 5. API NUM.ERICAL CODE 6. LEASE DESIGNATION AND SERIAL NO. ,~aval Petroleum Reserve #4 7. IF INDIAN, ALLOTTEE OR TRIBE NAME N/A 8. UNIT, FARM OR LEASE NAME N/A 9, WELL NO. 12 10. FIELD AND POOL, OR WILDCAT South Barrow 11. SEC., T., R" M., (BOTTOM HOLE OBJECTIVE) Section 26, T22N, R17W 12. PERMIT NO. 13. DATE SPUDDED f4. DATE T.D. REACHED 115. DATE COMP.SUSP OR ABAND. f16. ELEVATIONS (DF, RKB, RT, GR, 1!:TC)" 17. ELEV. CASINGHEAD 10 MAR 74 16 APR 74 04 MAY 74 KB=26'MSL r . # 18. TOTAL DEPTH, MD & TVDr9. PLUG, BACK MD & TVD . IF MULTIPLE COMPL., 121. INTERVALS DRILLED 8Y 2287 2088 HOW MANY" N/A ROTARY TOOLS . ~ CAIILE TOOLS . 2287 -.it _ 0 22. PRODUCING INTERVAL(S), OF THIS COMPLETION-TOP, BOTI'OM, NAME (MD AND TVD)- . 23. WAS DIRECTIONAL ; SURVEY MADE South Barrow Gas Sand. Geological particulars on file with Officer in Char~e Yes j 24. TYPE ELECTRIC AND OTHER LOGS RUN DIL, FCD, CNL, BGT, lIDT, BHC, CBL, BROX-ML 25. CASING RECORD (Report all strings set In wEll) CASING SIZE WEIGHT, .LB/FT. If GRADE DEPTH SET (MD) HOLE SIZE CElIIT..l'l!TING RECORD A..'\-IOUNT PULLED 16" 75# NaO 160' 22" 345 sx Permafrost 0 103A" 51# PSI 1067' . 14(4" 950 sx Permafrost 0 7" 23# ~884' 91'8 " 340 sx Perm. , 270 sx Class "G" 0 26. LINER RECORD TOP (MD) T7. BOTrOM (MD) SACKS CEMENT- SCREEN (MD) SIZE 2062 0 slotted, 2 % II SIZE I) II? II 1884 28. PERFORATIONS OP!:N TO PRODucnON (Interv'l1, size and number) TUBING RECORD DEPTH SET (MD) ! PACKER SET (MD) 2053 N/A 29. ACID, SnOT, FaA.CTURE, CEL10ŒNT SQUEEZE, ETC. DE?T!I INrERVAL (MD) A.J."VJ:OUNT AND KIND OF MATERIAL USED Never produced 30. DATE FIRST PRODUCTION PRODUCTION Never produced DATil OF TIIST. HOURS TESTED CHOI<E SIZE jPROD'N FOR r TE.S'l'~ ?1 APR 74 , FLOW, TUBING CASING PRESSURE CALCULATED OIL-BBL. PRESs. ~ . 21-HOUR RATE 'I I )10 31. DISPOSITION OF GAS (Sold, uled lor Ivd, vented, etc.) WELL STATUS (Producing or Sllut-ln) Shut in ,GAS-MCF. WATER-BBL. ¡GAS-OIL Ri\.TIO WATER-BBL. ]OlL GRAVITY-API (CORB.) o N/A {TEST WITNESSED BY A. Crane PRODUCTION METHOD (Flowing, gas lift, pumping-size and type of pump) OIL-BEL. I o GAS-MCF. 1 360* 32. LIST OF B.TTACBMENTS 33. I hereby certify that the foregOlng.~nd a . Z:for~atIO:~O~I.nd correet as determined from all available records SIGN::--:'~ ., -......:xTL;rë}fflcer in Charge DATE 2-28-75 R.V.Shafer.T.CD F.C.USN *(Sce Instructions and Spaces for Additional Data on Reverse Side) -,.-------- RE: Smith Barrow #12 1890-2058' This interval contains spotty occurrences of rare calcareous foraminiferà, the preservation of which is genexally too poor to allow speciation. AGE: Jurassic (Undifferentiated) 2058-2210 ' This interval contains many calcareous species characteristic of the Lower Kingak Shale. These species are listed on the acco~panying distribution chart. This is the first good . "cleanvater" shelf marine interval found in this well. AGE: Early Jurassic 2170-2265 ' There v..as rare faunal evidence present in the core at 2170 f·eet to indicate a Triassic age. The Shublik Fm. call here (2210') is baSid on lithologic evidence .(i.e. change to medium grained shelly sandstone). AGE: Triassic 2265-2;:83 f 'l1~D. Dark gray to black argillite basement. Considered by most to be Cambrian-Ordovician in age. Barren of foraminifera. Al'WERSor~, .HLCOXON " ASSOCIATES, INC. /S¡!y¡¿,~j)e {2~£.~-..-~ . R~chard E. Ancerson -2- '\ ¡ I ¡--. H-· 1·'·]'------ ANDERSON, WiLCOXON & ASSOCIATES. INC. ---------------------- CONSULTiNG MICROPALEONTOLOGY ~_.__._--- 11526 Sorrenlo Valley Road Suite G San Diego, California 92121 (714) 755-1524 Cab.le: Micropaleo San Diego -_._------------~._.. '-- -.-- fl;l u l( --- ~,,$ .r €( TO: Tetra Tech, Inc. RE: U.S.N. NPR-4 South Bar:rOw 1112 26, 22N/17W North Slope, Alaska FINAL MICROPALEONTO~OGY REPORT The following final micropaleontological report is based on . 4IIÞ the examination and checklisting of 73 ditch samples and (4 conventional core s~~ples covering the inter.al 460 feet tü 2283 feet in the South Barrow #12 Well. Attached you will find a I' to lOO I faunal distribution log, ·a faunal chec;(- list, and a sketched correlation chart comparing this well ~Ii th the Iko Bay #1 !'lel1. Below is a generali zed age Slli~,- mary of the South Barrow #12 Well. 460-1545' This interval is characterized by a Verneuilinoides bor~~l~£ Zone fauna. The occurrence of glauconite Dictyo~it~ sp. at 520 feet suggests that topagorukensis Subzone this depth. we are in or slightly above the of the Verneuilinoiàes borea~~ Te,.:tulari2. _._-- Z,:me at. AGE: Aptian to Albian . 1545-1890' This interval is characterized by rare foraminiferal species suggestive of the Gaudryina tailleuri Zone, some raúging ~~ old as Late Jurassic. The fauna that tops at about 1800 feet is probably Late Jurassic age. A~E: Neocomian to Late Jurassic ,.------- ---~----_._--- ------"-..---.-.---, -'^'-.".--'- ---- ---~. --~--_..- - RE: Husky/U.S.N. - South Barrow ~12 550-1460' (includes sample gap between 830-1080') Undifferentiated bisaccates (C-A). Classopollis classoides (R), striated bisaccates (R, reworked). Astrocysta cretacea (F-C) , Broomea jaegeri (R), Cyclonephe- lium distinctum (R-F) , Odontochitina operculata (R-C) , Oligo- sphaeridium complex (F-A), Gardodinium eisenacki (R),·Muder- ongia sp. (R), Ovoidinium verrucosum (R). Rare, reworked occurrences of Gonyaulacysta jurassica, G. cladophora, Ctenidodinium ornatum and Sverdrupiella usiata. AGE: Aptian - Albian (possible Aptian?) ENVIRON~ŒNT: Marine The rare and consistent occurrence of Garàodinium eisenacki makes this interval correlative with similar zones assigned to the Aptian in nearby wells of the region. However, the dinofla- gellate species, Ovoidinium verrucosum, occurring between 1080 feet and 1300 feet, has a known range of Albian-Cenomanian. If Q. verrucosum is indigenous to this interval, then an Albian age ·assignment would be proper. Unfortunately. other wells examined in the vicinity have not clarified the subdivision of this Aptian-Albian section. 1460-1870' Undifferentiated bisaccates (C). Astrocysta cretacea (C-A) , Broomea jaegeri (R-F) , B. pellifera (R), Cyclonephelium distinctum (F-C) , Oligosphaeridium complex (C-A) , Odontochitina operculata (C-A) , Gardodinium eisenacki (F-A) , Cribroperidinium edwardsi (R), Muderongia cf. staurota (single), Nannoceratopsis gracilis (single, reworked). -2- '\ ·-f----·~- ':.. 'I~ )1 ~ , ----- -----~-- CONSULTING MICROPALEONTOLOGY 11526s;;;;;V~lIey R~~ Suite G =- S;-;;-'iii-;go. California 92121 (714) 755-1524 Cable: Micropaleo San Diego ------ -----_.....~ January 31, 1977 TO: Tetra Tech, Inc. RE: Huskv/U.S.N. South Barrow *12 Sec. 26, 22N/17W North Slope, Alaska REVISED PALYNOLOGY REPORT . h b· t well have recently be~n restuü~ed The slides from t e su Jec and it is necessary at· this time to revise the palynology in- terpretations. 460-550' Undifferentiated bisaccates (A), stri~ted bisaccates (R, re- woryqd). Astrocysta cretacea (A), Broomea jaegeri (R), cyclo~epheliu.",. distinctum (R), C: compactum (F), Odontochitina opercalata (F), Oligosphaeridium complex (F), Australiella cf. sverèrupiana (single), Sirmiodinium grossi (single, reworked). AGE: Aptian - Albian ENVIRONHENT: Harine A single specimen of the genus Australiella indicates t._~ above 46Q feet there may be some Late CretaceouS, or a~ ~~, reworked Late Cretaceous rocks present. --- RE:. HuskY/U.S.N. - South Barrow #12 2265-2266' Barren of palynomorphs. Black organics recovered. AGE: Indetermina te ENVIRONMENT: Indeterminate ANDERSON, ¡'IARREN & ASSOCIATES, INC. þ{¿¿_"r, A~/-- I'rlid~Ý~Haga -4- '\ -----'----- _._·····'..0··_'·'·.·..,"""__·'.·. ------ --"- ---'.,-- RE: Husky/U.S.N. - South Barrow #12 1460-1870'· (con't.) AGE: Probable Neocornian ENVIRON~ffiNT: Marine The pr91ific dinoflagellate assemblage is very characteristic of the Neocomian interval in the North Slope region; however, certain more age-restrictive species are lacking, or only single specimens were found. Due to this deficiency only a tentative age assignment is possible. 1870-2089' .. Undifferentiated bisaccates (C-A), Vitreisporites palliàus (R-F), Classopollis classoides (R),· ~srn\lndacidi tes ",'ellmanii (R), Rogalskaisporites cicatricosus (R), Callialasporites darnpieri (R). Micrhystridium spp. (F). AGE: Undifferentiated Mesozoic (probably Jurassic) ENVIRONMENT: l.!arginal l-!arine 2200-2210' Heliosporites altmarkensis (R), ?Gleicheniidites nilssonii (R), Callialaspori tes darnpieri (R). Micrhystridium spp. (R). Þ~sozoic (Triassi!IIÞ AGE: Undifferentiated Jurassic) Nonmarine - ~!arginal Marine ENVI ROm'lENT : -3- J. S. Nð,vy S. BARROW #/2 2~J2Z;.J117W' No s"'....plcs ~'~S::\:>: - ( I¿n-Apf,.~ :~ ~I.J~O'~ IsIS- . .J. __ u..,_ _ _ _ _ _ _ ---53!:' I A/b U. S, Newj \ \<'0 ß.A Y ~. ICoJlIN/I£::' W I"~ ,~,'" "- "-. No Sc.""p\~S sli,~/"/~ 18(/~ ~ '>So . '> Blo' loeo,-IDOt SJO'- --- - _ -7So~ "-\..' ,- AGE'? ,,-:.9vn~ 'Z~ ~f~: /i/b/~fi -ApHt:i¡'¡ ~ o ~ ~ . 15!.JS , VeÚ'o/l~/',-<n L ,de JlJ,rC¡.LC,c.. Jï: . ( '{/' -L. ') .'8'10' ~ IÂI-o..sSI Co U"d;, ..·e reI', 1"0. ie d :oss,-2DDC .- [;CI,I"/Ij_ _ _ _ _ _2136' :z.170' -- - - ---:::::::: ¡: 7.1 0 ·2ZID - - - -Jü,.-o.5Sic ::::::::-----: S hu b . K r,". 22 ("S I -./ Arj:/1;·h. ---- /lr~¡JI, h " -S60 I - - \/e,..-héto. ( ÇÚ.Jf.. - - -:-0 Nt> Horjon fo./ SCt1íe. -i·;:".:;;' O~'P¡KRü.4K ShALE.. -;> ?_?_?_7....:..J . . . . IJ i3~D' ~ 20:;0' ~!.Jj ~"""j ~~ " v) 2'-1'-/8" _ 25L/-' , 5H'J8Ll.'( r;~., '-'"'~ 27DO A .11.\ ¡-¡rJ'dlTe Ak/.A. 6/17/15 '\ þ " U. S. NAVY N.P.R~ ~4- is'~'';.l)'~~~~W¡!¡:#'£2· 2 6, 2 2 N 11 7 W N. SLOPE, ALASKA FAUNAL LOG . _200' MARINE . -,'> 0 5 10 0 I I I I I I I I I I _100' 50' o ' VERTICAL SCALE . 500' ALBIAN-APTIAN ^ 1000' SAMPLE GAþ TOROK rH. v . .. .. 1500' 2000' . () ',.i' . . ALBIAN-APTIAN 1545' ^ ' _~__ . .,.~ .;~It_N.. .,' ,/-, 3 NEOCOMIAN LATE JURASSIC 1"890 ' _ ........'_R ..~. _~ _ .,_.~... ......_._,.. . <~_~. ._... ~ > JURASSIC (UNDIFFERENTIATED) 2058' ~. EARLY JURASSIC 2170' ~ TRIASSIC --==_ (Caving :~int) ~ .~__ .. _ 2? 62.:-____"'---------.....-....-..,,_-.-, A.W.A. 6/17/75 OKPIKRUAK SHALE? . ? ? ? ? ? ,.--...... .. -.-' .. --., .. -..,-..-.. _.,.- KINGAK SHALE " ; 2210' SHUBLIK FM. - -, ..........-.----.....- ARGILLITE .-, C L - 690 aRE LABORATORIES. I~ PRELIMINARY CORE ANALYSIS n.u~ #1/.,,,¡ COMPANY U. ~. NAllY WELL 5011(.7"'- t3AARow ~ '"L- COR". 1), ¡t'''''''UI,j , C.OIUU. FILE No. R¡:!.3 -31.'( :;I..;~ cTAT"IIIIISbl FIELD S.", ~ '"ßARIl't...J ""ß~ OIL TOTAL /ic::A.»ÑC. OIL PERII£A8ILm POROSITY WATER ruu IL[ ~L;;R~S % P2'¡E P~E ,u___. .o~ V~L. 2..~ t.~ 1. :r! Z1! t'~ t1: t'j II. REC. DEPTH FEET "., 1.1..D"I- o~ s (. '.! 1- ~! 1$!.. 'I1!=. ,I/. 2.0! 13!. '1!. ()~-O" ,.!.. o..!. ¡.¡! .3.~ "~ 100 ~ r ~ 10 - II J,.1.. I." - 9'. - "'- "., ... ( ð" t Jr.,,) 2.0..10 .".., 1,1/- I~-IS' 101. I.t 2.1~ f.! S't! 'L..'" II$' U 2.1.! " t 5' '!.. "L.1..I' - 19 SS"&." t"! I J !. ~':. " . ?.., l.1..1.1.-2.'J ~ L' - Z.r~ 1/1- z.&I-z.$" U' t.! t1.! ,,,!,,,! ,.., If 3 ZL-Z:7 lOa.. t.í - 3"= 32.- 2.'-z.f """''S 1.2. '!. t'Z.~ $) ~ I(f ,,.., .3.-.3) Is1 z.'- 30- t'- 1'L1. .... 1 ., .)L-)'> $' Z. c - 3'''' 3'... 3't-))' z.' .., 14 ~ 31..}. .¡...! 3'-37 z. t 1J I" ~ "Lt.! .¡s! 1'''31 t.&f .,. ~ 2,0:! %'t! "1~ 11'1 " 'f.-'' ,.,. 2,:\- 31- 31~ 1'¡. " t ... I ch-'tJ t.~ 2.1 - 33.... ~- JStl I ~ .... ","."'s 'II- ...1... 30.... ,.... "/1-'11 "IS'I I' t.,(! st.!. 2.' ~ z.z...~/-~'f 413 )~ I'I!. 1.S1 .¡s! Zt.S1-5' '41 9.~ 2:2.!. ,¡;!. f,!. sf-¿,. JI$' 41. 2.,1. 2.51 ;/.! '1-'7... ¡AI. ,t.!. z.1.~ ~,!- J'. . 'L'1..Id·'' st.. ", Z.1I.t 3'.1 "i. !. (1) ALTERED CORE (2) EXPOSED CORE (3) INSUFFICIENT SAMPLE 01.-07 z.!! Z,'''! z.7j t.~ z?! t.~ r.'! 'Z. '*J 1-'1 2. ,,-' z.'.! z.~ z.1:! z.~ z.~ z.1:! z.':! 1.!! z..~ COUNTY A/./t'TI.. DRILLING FLUID GAS % VOL. FL UORE~ ODOR CENCE FORMATION DESCRIPTION .ss, u ', '5/1; t/ .., r'1Æ. .... t/ ,/ V' ", "" t/ s t, Iy v v V' ",. v v v' t/ v ." v '¡'¡'" C"·,· .J,;: . VED v' APR 1 9 1974 v S 'I Ff I ,/~, vi N AVPETRES, ALASKA jS, ø ~1) s/l", t/ v py'" V' V t/ v 1/ If ..... ,~, II ~ .f, I s ''7 I rlf"" V' v I' t/ v ... "" *LN'~A#J V t/ V' (4) CORE CONTAMINATED BY DRILLING FLUID (5) REFER TO ATTACHED LETTER (8) LOW PERMEABILITY This Is A Preliminary Copy of Data Submitted Upon Request and Is Not A Final Report :ompany U. S. Navy . . CORE LABORATORIES. INC. Pe/ro/cm" Rescrvoir Engh/eering DALLAS. TEXAS Formation ¡·cll._.?_~uth Barrow Gas Well /;12 'ield South Barrow :Ounty North Slope ocation AMP!..!!: UMBER DEPTH FEET 1 1966-67 73-74 80-81 89-90 1997-98 2005-06 13-14 21-22 29-30 35-36 37-38 39 -40 41-42 43-44 45-46 47-48 49-50 51-52 53-54 55-56 57-58 2059-60 ') ... 3 4 5 6 7 8 9 o 1 2 3 4 5 6 7 8 9 o 1 2 State PERMEABILITY MILLIDARCYS HORIZONTAI.. VERTICAl.. 9.1 8.1 22 55 42 48 3.1 26 3.1 1910 25 434 2845 3295 637 189 13 4.1 41 42 17 0.6 0.6 1.3 10 3.8 23 33 0.9 8.1 0.9 1650 23 312 2725 2325 98 165 5.9 22 71 55 3.4 0.3 Cor~ Diamond5 Conv. Alaska Drilling Fluid WBM Page 1 of 2 File BP-3-324 Date Report 4/17/74 Analysts WSP Elevation Remarks Conventional AnalYs·is CORE ANALYSIS RESUL 1'S (FiRur..! ¡If þllrnlhl'._'t's ,rlr, 10 loo/..o/r ,rtIJlI,/u) RESIDUAL POROSITY $A:rURATION PROBABU Grain PERCENT OIL J TOTAL PRODUCTION Boy1ef % VOLUME % PORE %~~~E Density 13.9 15.7 18.3 20.7 19.2· 20.7 13.6 18.5 14.8 27.7 17.2 22.6 27.2 26.8 21.4 19.8 13.9 11.5 16.8 18.6 ~15 .4 9.0 4.2 4.0 4.2 2.8 7.3 6.2 7.5 8.9 8.0 4.0 8.8 4.9 4.6 3.0 3.9 5.2 6.0 6.2 6.9 5.4 5.8 8.9 68.4 64.3 51.7 55.6 65.3 55.0 61.0 50.2 49.5 45.8 41.6 47.8 50.2 48.8 37.4 44.9 64.6 65.0 57.6 51.5 71.3 79.7 \. 2.65 2.65 2.66 2.64 2.65 2.64 2.66 2.64 2.64 2.62 2.81 2.64 2.62 2.62 2.68 2.62 2.73 2.79 2.74 2.65 2.69 \C REMARKS SSt vfgt altYt sh1y aa aa aa aa aa aa aa aa SSt mg SSt mgt sid. 55 t f-mg ss 5 m-cg aa SS, mg, s1ty ss t f-mg, slty SSt f-mg, v slty SSt fg, slty, shly aa sa aa SSt fg, slty, v shly TE: I REFER-TO ATTACHED LETTER. (2) OFF LOCATION ANALYSES-NO INTERPRETATION OF RESULTS. , INCOMPLETE CORE RECOVERY-INTERPRETATION RESERVED. These analyst'S. opinions or Interpretations are based on observations and materials supplied by the client to whom. and for whose exc:IIJSIY~ and confidential use. this report Is mAde. The Interpretallonsot opinions ex-pressed represent the best Judgment .of Core Laboratories.. Ine. (all errors and omlssiOlU u- ~1J1"IIdi);: ibtit ~~ JU~~ tn~... and Its..ofth~@" 1I~!t I!","'öy~~, 1I":'.um' )11:' "'i!lýjIjH.. blt~t,y 1I"~<.MII~.r..;I\O: \\(jI~ti'i!f ~~I t,a~~cr~.,IIa..,to_ .~he productivity. I 1 I 'to l!ro"r-J: ·ORE LABORATORIES, INC. . Petro/elm1 Reservoir Engineering DALLAS. TEXAS U. S. NAVY Formation Page 2 of 2 11'.1n)" ---~-~...._-_.- SOUT~_BARRQW GAS_RELL NO. 12 Cores---º.Ii\MOND, CONV. FileJP.--:J..::JZ4 I SOUTH BARROW Drilling Fluid WBM Date Report_!tLl.ZL74 IHy ...~9~!H SLOPE State ALASKA Elevation Analysts WSP Ition _ Remarks CORE ANALYSIS RESULTS (Figu'('J i" þ",(',,/ht'.JI'J ,('/(', /0 /0(1/"0/1' '1'",,,,/u) PERMEABILITY RESIDUAL 'LE DEPTH MILLIDARCYS POROSITY SATURATION PROBABLE Graio JER FEET HORIZONTAL I PERCENT OIL I ~~~~~ PRODUCTION REMARKS ·VERTICAL Boyles" VOLUME % PORE % PORE Deosity 2204-05 117 36 24.3 25.1 43.6 2.68 ss, vfg, slty 06-07 9.0 14 20.3 13.8 63.0 2.74 ss, vfg, slty, pyr 08-09 1.J 0.1 ,._~ 14...{,) }.4 77.0 2.77 aa 10-11 100 22 24.4 9.8 66.8 2.75 . ss, vfg, slty 12-13 44 20 22.5 8.9 64.9 2.73 ss, vfg, slty, shly, pyr ,"- 14-15 102 2.8 23.9 8.3 52.3 2.72 ss, vfg, slty~ shly 16-17 95 65 22.0 16.8 58.4 2.74 aa 18-19 55 26 20.5 > 13.9 59.2 2.70 ss, vfg, slty 22-23 68 52 21.7 28.3 41.9 .:""." fl.73 aa 24-25 35 8.7 22.5 19.5 49.8 2.74 aa 26-2~ 194 ·102 25.9 34.2 32.3 2.71 aa 28-29 44 23 22.4 22.2 53.6 2.75 ss, fg, slty 30-31 168 139 26.1 30.8 29.9 2.66 ss,fg ~!>' 32-33 122 56 24.2 37.8 31.4 i.67 ss, vfg, slty 34-35 21 13 19.6 32.1 42.0 2.67 aa 36-37 28 13 19.6 22.8 45.5 2.68 aa 38- 39 24 4.6 ·20.4. 22.0 47.6 2.69 aa .- 40-41 151 108 23.1 31.8 37.2 2.65 aa 42-43 74 8.2 21.6 33.8 35.1 2.66 aa 44-45 154 72 23.1 30.2 30.2 2.64 aa 46-47 459 16 25.9 36.0 27.6 2.65 aa 48-49 43 15 19.9 25.7 45.0 2.70 aa ---- -, - .-.- --'- - "".-.........~- -~_..._- 57-58 47 9.4 22.8 16.2 18.8* 2.69 aa *Exposed core 59 - 60 115 41 26.7 24.4 11.9* 2.67 aa 61-62 14 36 18.5 22.0 27.2* 2.73 aa 2263-64 361 63 24.8 31.8 611* 2.63 SS, vfg " REFER TO ATTACHED LETTER. (21 OFF LOCATION ANALYSES-NO INTERPRETATION OF RESULTS. INCOMPLETE CORE RECOVERY-INTERPRETATION RESERVED. 5e analyses. opinions or Interprelatlons are based on observations and materIals supplied by the ellent to whom. and for:WhO!le exeluslve and c:onfldenUal this report Is made. The Interpretations or opinions t!rP""ssed repreftnt the best. .Iudgnu!nt of .Core Laboratories. tnC!. (all. ~rs a\'ld omissions .ex- ....~,;; .1mJt if:!.!~ ~~iÞÐt_. b>.t.~. ~~t Us @tfl~1"3 ."it. "'m.I)I.I\,,\!<!~,.tI,",.",".e .nlt.. It"'I~'I"~I¡'" W HH.d¡tnat.ti,tto' Wa1!taJ'\t)'."ót 1f1!. ~I).\a~l~.... ,\1;1... ,.lo,.,U:,e prcHlIcUvlty. er·· opw...Uon, 01" proIltabl_· ~ IIA~ ..u. .... ... ...,., m",tI{a' wi!ll Iff ¡Nnt "".11111.0;10.... """tl1ifflffH !!Ù~fI' ¡L¡~\:'t. 1~'Ü~H'or r~I1-' ""C'. .. . CHa1tCAL 8 9EOLOGIC.~ LAÐORATORp:S OF ALASKA.IPJC. L . , t"~lJt. unto TE LEPHONE (907) 279-4014 P.o. BOX 4-1276 ANCHORAGE ALASKA 99509 4649 BUSINESS PARK BLVD. , . ANAL YTICA L REPORT Froaa.............. !:I.u ~ .kY.... O.iJ. ...Ç.ºffiP.ªJ!Y...................... ...... ....... ...;.Product........... . ....... ç~.!.~.~......... .............. ............. ....... .......... ... .... Addr.... ....... Ar¡.c.h.Qr.a.ge... A l.as. ka...,..........~..... ...... ............ ..._D.te..h.. .... N..º Y.~IJ).I? ~r. ~.. J. ~ZZ........~...... ...................... ........... .... Other Pc:rtlnfl'lit D.ta............................ ......... ............ ......... .... ....h......................... ..... ....... .....~................. ............................. ......... ..................... ... .......... ............ ....... ..... ...... ..... ..... ....... ............. ...... ... ............................. .... ... .... ~......... ..............'... ................................................. ..... .... ..... .............. .... ............. ..... ................... -....... .... AnaJysed by........... ..~~... .... ........................... ". ........... ..... ..... ....... Date ......º.~~.~~.~!:.:... .~.~ .!. ..~.~?? "'h...Lab H 0. ]003 .... ..... REPORT OF ANALYSIS CORE SAMPLES SOUTH BARROW NO.1? ~ NPR #4, ALASKA PROCEDURE: Selected core samples were analyzed to determine susceptibility of existing materials to exposure to various liquids. This effect was determined on several concentrations & liquids. LEGEND: Fresh Water:. (City of Anchorage) see attached ana 1ys is CaC12:- . Calcium Chloride (36.11% Calcium, 63.89% Chloride) CaC12 .25000~::: .25000 'ppm as CaC12=.9027.. Sppm asCâ=.15972. 5ppm as C1 Clay Sta = Halliburton Clay Sta, 2% solution Cl Gas = Methane gas, see attached analysis NaC1 = Sodium Chloride (39.34% Sodium~·60.66% Chloride) KCl = Potassium Chloride (52.25% Potassium, 47.75 % Chloride) Invermu1/0i1 Filtrate = Oil based mud filtrate supplied by Husky. All concentrations of solutions are Calcium Chloride unless other- wise noted. CC: Mr. Bret Allard Mr. Henry Peterson . ... . PAGE TlW % PERMEABILITY REDUCTION r . . . . . . . . . . . TIME. . . . . . . . . . . . . . . . DEPTH = 2036 FEET 15 MIN. 30 MIN. ONE HOUR Fresh H20 4.8 6.9 10.5 CaC12 25000 2.7 3.6 6.0 CaC12 -50000- --;, 2.7 3.8 4.2 CaC12 100000 2.5 3.6 3.9 50000jMud Fi1t/50000 81.6 80.4 79.0 5000Q/F.resb/50000 3.0 4.0 4.9 5000/Cläy- Sta/Ffesh/Cl aySta 2.7 3.3 4.0 Cl Gas/Fresh/C1 Gas 7.2 2.6 0.8 Cl Gas/5000Q/Cl Gas 6.9 2.2 0.1 Clay Sta/Fresh ~lay Sta 2.5 3.2 3.7 NaCl 50000 2.9 3.9 4.6 KC1 50000 3.0 3.9 4.2 Invermu1 / Oil Filtrate 96. 1 . . . PAGE THREE --- % PERMEABILITY REDUCTION DEPTH = 2042 FEET . . . . . . . . . . . TIME. . . . . . . . . . . . . . . . 15 MIN.· 30 MIN. ONE HOUR Fresh H2O 30.6 50.0 59.2 CaC12 25000 28.7 26.6 29.0 " Ca C12 50000 22.0 , 23.1 27.7 CaC12 100000 20: 1- 22.0 26.3 50000/Mud Fi1t/50000 69.4 67.6 67.5 _ 50000/Fresh/50000 23.6 - . - 26.4 28:9 50000/Clay Sta/Fresh/Clay Sta 23.0 24. 1 28.3 C,Gas/Fresh/C,-Gas 73·.3 20.0 10.1 . C,Gas/50000/C, Gas 55.6 ,1. 1 0..2 Clay Sta/Fresh/C1ay Sta 21.3 23.8 28.2 NaC1 50000 23.1 24.0 28.1 KC1 50000 23.6 24.2 - 28.6 Invermu 1/ Oi 1 Fil trate- 92.4 . ,..,...l1c' ruul\ .. . % PERMEABILITY REDUCTION DEPTH = 2044 FEET . . . . . . . . . . . TIME. . . . . . . . _ . _ _ _ - . . 15 MIN.· 30 MIN. ONE HOUR ~resh H2O 35.2--- 49.2 66.7 ". CaC12 25000 23.1 , 38.6 43.4 Ca C12 50000 22.6 33.4 41.3 CaC12 100000 20.6 32.9 40.7 50000 /MudFj It/-50000 --, -- 71.3 70.9 "- 70.4 50000/Fresh/50000 23.9 35.0 44.0 50000/Clay Sta/Fresh/Glay Sta 24.0 31.2 41.3 Cl Gas/Fresh/C1Gas 86.7 16.7 6.8 Cl Gas/50000/Cl Gas 80.0 12.6 0.3 Clay Sta/Fresh/Clay Sta 23.6 29.9 - 41.2 Invermul jOi-lFil trate 95.4 .. . . PAGE FIVE % PERMEABILITY REDUCTION . . . . . . . . . . . TIME. . . . . . . . . ~ . . . . . . DEPTH ~ 2054 FEET 15 MIN. 30 MIN. ONE HOUR Fresh. H2O 75.4 81.9 92.0 CaCl -25000 --- 60.4 , 65.6 70.1 2 . CaC12 50000 51 .4. 56.3 56.9 CaC12 100000 50.3 53.4 55.7 50000;Mud.F-:f1 t/50000 _ 95.7 _ 96.0 ., 98 . 6 .- 50000/Fresh/50000 55.6 58.8 60.4 50000/Clay Sta/Fresh/C1ay·St~ 55.4 58.0 - 59.6 - . Cl Gas/Fresh/C, Gas 91.7 30.3 7.0 Cl Gas/50000/C, Gas 90.6 21.6 1.9 Clay Sta/Fresh/Clay Sta 55.' 56.4 59.2 Invermul/0il Fil trate --- '- 99.2 .. . . PAGE SIX , % PERMEABILITY REDUCTION . . . . . . . . . . . TIME. : . . . . . . . .0 . . . . . . .. DEPTH = 20~0 FEET 15 MIN. 30 MIN.· ONE HOUR . Ka to. 1 ow.fo.r - Kl determinations tf1 ow blocked.· Sample pulverized. Fresh 95.-{) 96.8. - CaC12 25~00 86.1 , 88.3 CaCl2 50000 85.7. 87.6 CaCi2 1 00000 85.9 87.4 NO FURTHER TESTING-DONE. 97.5 - 90.4 90.1. 89.3 % PERMEABILITY REDUCTION ........... TIME................. DEPTH = 2048 FEET 15tH N . 30 MIN. ONE HOUR Insûffìc;ent' -sü~ tabl e-sampl e-for -plug- Kl. Sample pulverized. Fresh ·78.6 80.9 86.4 CaC12 25000 28.6 30.1 . 33.4 CaC12 50000 27.6 29.8 33.8 CaC12 100000 27. 2 ._~ -. 28 . 4 _. 30.6. NO FURTHER TESTING DONE. CORE LABORATORIES, INC. Petroleum Reservoir Engineering DALLAS.TEXAS Special Core Analysis Study for TETRA TECH, INC. Navy NPR -4 South Barrow No. lZ Well Northern Alaska . . CORE LABORATORIES, INC. Petroleum ReJervoÙ· Engineering DALLAS. TEXAS February 8, 1977 Tetra Tech, Inc. 4544 Post Oak Place Suite 266 Houston, Texas 77027 Attention: Mr. Rems C. Heiny Subject: Special Core Analysis Study Navy NPR-4 South Barrow No. 12 Well Northern Alaska Your Job Order No. 22-7034 File Number: SCAL-76385 Gentlemen: In a letter dated November 22, 1976, R. R. Simonson, requested Core Laboratories, Inc., to perform Mineral Content Determinations by X-Ray Diffraction on five sandstone samples and Liquid Permeabilities determined as a function of volume throughput on one sandstone core plug. It was also requested that we not start analysis until a purchase order was submitted. On November 30, 1976, a purchase order was submitted by Rems C. Heiny; however, Core Laboratories, Inc., did not receive the purchase order until January 7, 1977. The results of the requested anal- yses are submitted herein. The core samples used in this study are identi- fied as to well, depth interval, and sample number on Page 1, and are lithologically described on Page 2. Irv Tailleur of the United States Department of the Interior Geological Survey submitted five sandstone core samples, each representing a dif- ferent depth interval between the depths 2206 feet and 2248.5 feet, for use in this study. A portion of the five sandstone core samples was reduced in grain size to less than 400 screen mesh (0.0015 inch). Each sample was analyzed for mineral content using an x-ray diffraction technique and CuK radiation. The amounts of minerals present were determined by comparing the peak . . Tetra Tech, Inc. Navy NPR-4 South Barrow No. 12 Well Page Two intensities of the diffraction scan with those obtained using standard mix- tures. The results of the mineral content determinations by x-ray dif- fraction are presented in tabular form on Page 3. Quartz was the pre- dominant mineral in each sample. Clay-type minerals (kaolinite and illite) were present in each well core sample in quantities ranging from 2 to 4 per cent of the total sample. One core plug, from. a depth interval of 2226 feet, was selected for the liquid permeability as a function of volume throughput determ.inations. The air permeability and porosity were determined on the core plug iden- tified as Sam.ple 3. The core plug was then evacuated and saturated with a brine containing 100,000 ppm. sodium chloride plus 30,000 ppm. calcium chloride. Liquid permeability as a function of volume throughput was de- termined on the brine-saturated core plug. Liquid permeabilities were also determined as a function of volume throughput using a brine containing 100,000 ppm sodium chloride followed by distilled water. An examination of the test results indicate that the core plug exhibited moderate sensitivity to the sodium chloride brine containing calcium chloride. No additional sensi- tivity was noted when the sample was contacted with the 100,000 ppm sodium chloride brine; however, a marked sensitivity was exhibited to the distilled water. It was a pleasure working with Tetra Tech, Inc., on this study. In the event that we can be of further assistance or should you have any questions per- taining to these test results, please do not hesitate to contact us. Very truly yours, Core Laboratories, Inc. p~i Duane L. Archer, Manager Special Core Analysis DLA: JWW: dr 10 cc. - Addressee Company Tetra Tech, Inc. Number of Wells One Field Sample Number . Company CORE LABORATORIES, INC. Petroleum Reservoir Engineering DALLAS. TEXAS Formation County State Identification of Samples 1 United States Navy NPR-4 South Barrow No. 12 2 3 4 5 . Page File Northern Alaska Well 1 of 4 SCAL-76385 Depth, Feet 2206 2216 2226 2236.5 2248.5 CORE LABORATORIES, INC. Petroleum Reservoir Engineering DALLAS.TEXAS Page Z Of 4 File SCAL-76385 Lithological Description Sample Number Description I Ss, brn, fn-v/fn grn, ca1c, mod indurated, frac 2 Ss, brn, v/fn grn, v/ s1l ca1c, mod indurated, frac 3 Ss, brn, fn grn, ca1c, mod indurated, w/clauc, foss frag 4 Ss, brn, fn-v/fn grn, well indurated 5 Ss, brn, fn-v/fn grn, v/ca1c, well indurated, foss frag · . CORE LABORATORIES. INC. P",ol,.", Iùsmlo;, S"gin,"';"g DALLAS,TEXAS P&¡'e File 3 of 4 SCAL-76385 Mineral Content Determination (by x-ray diffraction) Sample Depth, Feet: 2206 2216 2226 2236.5 2248.5 - Mine ra 1 Per Cent of Total Sample Quartz 88 55 49 72 63 Calcite 2 4 27 8 Kaolinite 2 4 2 3 3 Illite 2 1 Siderite 6 33 16 19 22 Pyrite 2 4 4 6 3 Th_ analy_. ropiniou or interpretatiou are bued oa obMrvation. and material .upplled by the client to whom. and for wh_ exclual". and con8dential -. ~bj. report ia mad.. The interpretatiou or oplnioa. upr.... rep~nt the beat judJrment of Core Laboratories. Inc. (all errors and omiaalona excepted): but Core Laboratone.. Inc. and ita oSIeers and __I~ __ no reaponaibllltJ' anó make DO warranty or rep....ntation. .. to the pzoducti"ltT. proper ~ tlo... or profttablen_ of any 011. ... or other minerai well or sand In connection with ..hlch auch NpGrt ia uaed or relied upøD. . . CORE LABORATORIES, INC. Pmol""" IùsmlOW &Iin,-; DALLAS.TIIXA8 Pap FilA. 4 of 4 SCAL-76385 Liquid Permeability Data Sample Number: 3 Porosity, Per Cent: 25.1 Air Permeability, Md.: 283 Liquid Throughput, Liquid/ Air Permeability, Md. Pore Volumes Permeability Ratio 100,000 PPM Sodium. Chloride plus 30,000 PPM Calcium Chloride 135 3.0 0.477 138 6.0 0.488 136 10.0 0.481 138 15.9 0.488 139 20.6 0.491 134 134 140 136 137 100, 000 PPM Sodium. Chloride 4.7 10.3 17.2 24.6 32.9 0.473 0.473 0.495 0.481 0.484 42 19 15 12 11 29 Distilled Water 2.5 6.6 12.1 18.6 22.1 (Reverse Flow) 0.148 0.067 0.053 0.042 0.039 0.102 Th_ aDAI~. ODinions or inte'lIretatloDB are baaed on obeervatioDB and material supplied by the client to whom. and for wh_ Gclui.e and conftdentlal -. this report Ia made. The interpretatioDB or opinions expreued rep....nt the beat judament ol Core Laboratori... Inc. <all errors and omiaaiou excepted); but Core Laboratories. Inc. alld Ita officers and _pl~ __ 110 reapoDBIblllty aná make no warranty or rep_tatlou u to the productivity, proper opera- tlOll, or profttablen_ of all)' oil. ... or other mlaera1 well or _lid III conll8Ctlon with wbtch auch repoft Ia ùed or relied upoa. fJ f) CORE LABORATORIES, INC. Petroleum Reservoir Engineering DALLAS~ TEXAS 75207 REPLY TO BOX 10185 CABLE CORELAB April 23, 1974 Naval Petroleum Reserve #1 Barrow, Alaska 99723 Attention: Lt. Commander R. V. Shafer, Offi cer I.n Charge Subject: Core Analysis Data South Barrow Gas Well No. 12 South Barrow Field North Slope County, Alaska Gentlemen: Diamond core samples recovered from the subject well were submitted to our Anchorage laboratory for permeability, porosity and fluid saturation determinations. The results of these analyses are presented in the accompanying report. We appreciate this opportunity to serve you and trust that we will be called on again in tf-e future. Very truly yours, CORE LABORATORIES, INC. ~C?~ James A. Cusator District Manager California Professional Engineer Reg. No. P-1176 JAC:gs UNITED STATES CANADA SOUTH AMERICA EUROPE AF"RICA AUSTRALIA ASIA HA - 1 (2/2/681 . REPORT OF ANALYSIS . F.S.- 16790 M.S. N-7237lf. ,H 2.55 OBS. PRES. 63.0 CAL. PRES. 53.6 STATE- ALASKr)!E COUNTY - s. WELL NAME- BARROW X NO. OWNER- u.S- GEOLOGICAL 12 FIELD- BARROW E LOCATION- N SLOPE SURVEY DATE COMPLETED- 0lf./05/74 DATE SAMPLED- 03/01/83 SAMPLED BY- R. V. f.IJURPHY NAME OF PRODUCING FORMATJON- JURA-BARROW SD L DEPTH IN FEET- 2031 THICKNESS IN FEET- 20 SHUT IN WELLHEAD PRES., PSIG- 855 OPEN FLOW, MCF/D- 360 CHECK OF DATA- THE WELL DATA ARE ACCURATE, ( ) WITHOUT CORRECTION,( ~ ) AS CORRECTED ABOVE. REMARKS- ANAL YSIS- METHANE 83.0 % NORMAL PENTANE 0.1 % OXYGEN 0.1 % - ETHANE 0.6 % ISOPENTANE 0.1 % ARGON TRACE % PROPANE 0.0 % CYCLOPENTANE TRACE % HYDROGEN 0.2 % NORMAL BUTANE 0.2 % HEXANES PLUS 0.1 % H2S *. 0.0 % ISOBUTANE 0.0 % NITROGEN 6.8 % CO2 0.3 % SPECIFIC GRAV 0.587 HELIUM 2.5'+ % TRACE DENOTES HE < 0.005% AND OTHER COMPONENTS < 0.059ó TOTAL 100.00 % CALCULATED GROSS BTU/CU. FT., DRY AT 60 DEG. F AND 30 IN. MERCURY- ~33 PERMISSION FOR RELEASE: Permission is hereby granted for the Bureau of Mines to release the above data, together with similar data released by other operators as public information and as parts of a series of papers on analyses of gases from various fields, states, or regions. J.. COM~O~ BY Max C. Brewer TITLE Contracting Officer's Representat MAR 30 'S8 þC~:i:"'m"'.~_,,~ '". CORKLABORATO PII,tII__ R,s-w E""""';"11 DALLAS. TEXAS DC-L-t-e 'sCLt??p(e.-J ; Ap~ //~ I 9?~ D a..-7::-e c> F c...c ve~ ,';'--3 Ie.. tle.r ; IV" Y. ~.J ) 9 7'1- Pue 7 of .11 ),.. . - File RFL 74268 Company U.S. Navy Formation Mohr Sand Wen Barrow No. 12 County Field Barrow Gas Field State Ala ska HYDROCARBON ANALYSIS OF Wellhead GAS SAMPLE .. COMPONENT MOL PER CENT GPM Helium Hydrogen Hydrogen Sulfide Carbon Dioxide Nitrogen Methane Ethane Propane iso-Butane n-Butane iso-Pentane n-Pentane Hexanes Heptanes plus 0.92 Nil Nil Nil 7.88 91. 45 0.56 0.06 0.01 0.02 0.01 0.01 Nil Nil 100.92 0.141 0.017 0.003 0.006 0.004 0.004 0.175 Calculated gas gravity (air = 1.000) = 0.590 Calculated gross heating value = 934 BTU percubicfootofdrygasat ~4.65 psiaat 600 F. Collected at 675 psig and 51 0 F. Th.. alUll:r_ opÎIÚOns or inter¡tretat1cma are hued 011 oIIMI'fttiOIl8 &lid materiallll1ppJied by the clieat to whom. &ad tor .a.- exclUli.... aDd a>IIRofentl- -. thla ~ is _de. The Interpretatioll8 or opinion. GpI'eIHd represent the beat juda'meDt of Core IAboratori.... Ine. (all _no... and omfaalOllll excepted): but; ~ ~~~~.~ .~~. .and ¡~ oØIeen and emp!o:r-. _ DO ~bill~,. aJU! make no warranty oa: repreaentatio..... to the productivity. proper opera. -- ~ - --'- _.1 __... __ ....1-1-__ _~_....__t __...." __ ......._.4' ..... .........".............~,..n T"I'"",+t, """'};",.,k a",." 1"'pnort, 1!:; 11~~ or rpHPrl n'f\nn. STATl- ,1\'1.A SK A 139 SO . M.S. I N-S9S44 ~ H 3.64 OBS. PRES. 67.3 CAL. PRES. 65.9 F. S. - COUNTY- N OT iG IV EN FIELD- BARROW S NO. 2 WELL NAME- B ARRO W S. oJ o. 12 LOCATION- SEC. 23. T24N. R17W OWNER- U . S. N A V Y DATE COMPLETED- CST DATE SAMPLED- 04/21114 ¡ h j.~ C .'~ .i. 'V ì~ D SAMPLED BY- ANDR EW F.> CRANE NAME OF PRODUCING FORMA TION- .JURA- fMW 8:! 1974 DEPTH IN FEET- zoa7 THICKNESS IN FEET- 73 I\TAV...·,··,...,-;-.·t. F'· ,tc'P'1I .I.. ' .l.J.:,.LJ.l~,,), &".:.Lè..u,¡,I..L' >HUT IN WELLHEAD PRES., PSIG- .810 OPEN FLOW, MCF/D- '500 ... :HECK OF DA T A- rHE WELL DATA ARE ACCURATE, ( ) WITHOUT CORRECTION, ( ) AS CORRECTED ABOVE. ~EMARKS- ~NAL YSIS- IfIETHANE .81.3 % NORMAL PENTANE TRACE % OXYGEN 0.0 :THANE . 0.4 % ISOPENTANE I 0.1 % ARGON TRACE % )ROPANE , 0.1· % CYCLOPENTANE TRACE % HYDROGEN TRACE % ..¡ORMAL BUTANE . 0.1 % HEXANES PLUS 0.1 % * H2S . 0..0 % SOBUTANE ·'0.1 % NITROGEN 1.9 % CO2 . ·0.2 % ;PECIFIC GRAV I 0.SÕ4 HELIUM 3.74 % rOT~L .......""'" ~ nl .i.uu.u IV :ALCULATED GROSS BTU/CU. FT., DRY AT 60 DEG~ F AND 30 I~. MERCURY- 910. DUE TO THE· ABSORPTI.QN OF H2S DURING SAMPLING.. ;THE .RÉP ORT.EO RESULTS MAY NOT BE RElIAElE. )ERMISSION FOR RELEASE: )ermission is hereby granted for the Bureau of Mines to release the above data, together with similar data released )y other operators as public information and as parts of 0 series of papers on analyses of gases from various fields, states, or regions. Üfiiwr in Cii;'HTI'~ COMPANY i'.;.~.. .j; P~'tti''':''''I....:1 ::....._,...- ", G;,rrC'\.ò/" t,J< ~/'.ô:~ ~ ~~-..\. .., BY TITlE . ~ñ: ·iJ~~t~~1 I ~11:i1 mãctl1 usn :. S. - 11.;003. M.S. N-59930 ,H 2.53 OBS. PRES. CAl. PRES. 63 . 'J )TATf- ~-LA SK A COUNTY- NOT :GIVEN :IELD- 34P.RO\. S WEll NAME- BARROW $I NO. 1'2 .OCA TION- SEC. 23. T2l.¡N, R17W OWNER- U.5.. NAVY . 05/05'/74 )ATE COMPLETED- 115/04/74 DATE SAMPlED- iAMPlED BY- j). B AR NE T T MME OF PRODUCING FORMA TlON- JURA- )EPTH IN FEET- 2081 13 THICKNESS IN FEET- 'HUT IN WEllHEAD PRES., PSIG- SlQ '50a OPEN FLOW, MCFjD- ... :HECK OF DA T A- 'HE WELL DATA ARE ACCURATE, ( ) WITHOUT CORRECTION, ( AS CORRECTED ABOVE. :EMARKS- '- ~NAlYSIS- ^ETHAN E 50.6 % NORMAL PENTANE TRACE % OXYGEN 0.0 % :THANE , 0.7 % ISOPENTANE C'-1 % ARGON TRACE (1,- >0 'ROPANE Tr~ACE % CYCLOPENTANE TR ACE % HYDROGEN 0.0 % ~ORMAL BUTANE , 0.1 % HEXANES PLUS TR ACE % * H2S o .J). SOBUTAN~ 'T Rt. CC: % NITROGEN 5.6 % CO2 0.3 % iPECIFI~ GRAV 0.517 HELIUM 2.60 ~;g ,.,.,..,.. . ! no.o % ....,."'- :ALCULATED GROSS BTU/CU. FT., DRY AT 60 DEG.'F AND 30 IN. MERCURY- ( 933. OIJE TJ THE AESOP-PTION .OF H2S DURING SAHPLING, .THE REPORTED RESULTS MAY NOT BE RELIABLE. ÞERMISSION FOR RELEASE: . Þermission is hereby granted for the Bureau of Mines to release the above data, together with similar data released ,yother ·operators as public information and as parts of a series of papers on analyses of gases from various ields, states, or regions. . OHkl"lf in Char~ø COMPANY!\!., ,--_I fL --_: .- Î.. , . JI' ~. .... ..'.......'...,~ .._'..~J,\"l.r :.-;,;:;., (\;,.rn1w, ¡\:( ') //.:.j, BY TITlE R. V.· SHlU'ER LCrHl I C:illC. USK F. S. - _ 13935 . STATÈ- ' '.At.A SK A M.S., N-S9 ~Ol ,H: 3.59 OBS. PRES. 68.D , CAL.. PRES. ,61.5 FIELD- 8 ARROW ~ NO. 2 COUNTY- NOT ¡GIVEN . ):::;0=-=;;:. WELL NAME- 8 AR RO W SI NO. 1 2 lOCA TION- SEC. 23. T2QN, R11W- OWNER-· u. S.. N A V Y DATE COMPLETED- NO T G1 liEN DATE SAMPLED- 1 NO T 6I V.E N SAMPLED BY- A.F'. CRANE NAME OF PRODUCING FORMATION- J UR,t\- DEPTH IN FEET- ; NOT GIVEN THICKNESS IN FEET- NOT GIVEN SHUT IN WELLHEAD PRES., PSIG- 300 OPEN FLOW, MCF/D- NOT ¡GIVEN ... CHECK OF DATA- THE Well DATA ARE ACCURATE, ( ) WITHOUT CORRECTION, ( AS CORRECTED A80VE. REMARKS- ANAlYSIS- METHANE ;87.8 % NORMAL PENTANE TR ACE % OXYGEN 0.0 ETHANE .. .0.-4 % ISOPENTANE , 0.1 % ARGON ¡TRACE PROPANE ¡TRA CE . % CYClOPENTANE . TRACE % HYDROGEN , 0.0 % NORMAL BUTANE . ·0.1 % HEXANES PLUS TRACE % . H2S , 0.0 ISOBUTANE ,TRA CE % NITROGEN . 7.1· % CO2 . D.1 SPECIFIÇ GRAV . 0.577, HELIUM 3..59 . ..~.. . . ClO 0 ...., ."'. CALCULATED GROSS BTU/CU. FT., DRY AT 60 DEG. F AND 30 IN. MERCURY- 904.· DUE TO THE ABSORPTION .O'F H2S'DURING SA1-1PLING,:THE 'REi> ORrED RESULTS HAY .NOT BE ~ELIABLE. PERMISSION FOR RELEASE: Permission is hereby granted for the Bureau of Mines to release the above data, together with similar data released ·by other operators as public information and as parts of a series of papers on analyses of gases from various fields. states. or regions. . .-: , : R. .~.. mIt..FER T..(:J)R .' C]iC. USN COMPANY BY O~f' . . -, . It.er In C....P.ig'.:l t:~'_'e; ~IC:r :}t~:;.~.,:·\ ~~ rq:-:".rVG f'..~J~);( BanGvi, ¡\i'~ \I.. .' ~~.j . .. TITlE ... . R~PORT OF M.S. t·;-5G133 ,r¡ 1... ü$ A~Al,(S;."-·: 035. PRES. .ó l; .. I;; F. S.- llt~2d i.... CAt. P~::S. - , '::""'"t. STAï'::- .., L.~ Si~ A COUNTY- N CR TH S LO F:: ~ ù;;{ ~U {;~~ F!2lD- I." .110 -; ",... .. . 0;: ... ...:. "tÙ .', ~ WEll NAME- e AR i(Q t·; s: 1\0. 12 tOeA TION- s¿c. 2~7 T22N7 R17~ OWN;R- ü -S.. Nr..V Y DA ¡i: COMPLETéD- '.. C~ / 11 / 7 ~ DATE SAM?lED- Q1:.1.13/74 " .SAMPLED BY- ~:~ N~ .;·1 It: :.,E LE T T I· NAN.E Cf ~RODUCING·FORMATION.- ~U~~-5~RROW SAND DEPTH IN fEET- ~:J :;0- ;z.C6-:S THiei<NESS IN FEET-· SHUT IN WELLHEAD PRES., PSIG- g/o . . Ie.:; 1:. - OPEN FLOW, MCF/D- . CH~C¡( OF DA T A- T:;E Vial. DATA ARE ACCU~ATE, ( " . r.:" ;:;:::0.- 9:> ...." ·..;-370 S'c;ó I1¿Fv. ) WITHOUT CORRECTION, ( ) AS CORRECTED ABOVE. - .~~.v,AR;'S- A~~A:' YS¡S- M=ï:iA~E S 2..3 % NORMAL PENTANE ·0. i} % . Eï!-iANE · 1:..8 % ISO?ENi'ANE .... ... % u..oJ P~O?ANE · .- 'to % CYClO?2NTANE · Q..û % u__ NO~MAL BUTANE · 0.. c·· % HEXANES PLUS · c.c % . tS03UïANE . . C.C· % NITROGEN · 4..e % SPECIFIC GRA V · C..57l -.- .' , _. OXYGEN ARGON HYD~OGEN $ H2S· C02 . HELIUM TOTAL CAlCU!.ATED G:{OSS BTU¡CU. FT., DRY AT 60 DEG. F ÅND 30 IN: MERCU~Y- 952.. 7.: :.:;:. Ti} 7.H£. ~~SO:~~~T!C~~ ·:Of:· ~';2:S DURI~I:G Si~~~::)·LI,··~5, .TH:': .HE? CilT:ED E ~:: ~ '..::... TS æ-\ A'f . :~ .JT .0 ë: RE'LI AgL~. :" ; .. ,.' . ¡ .., . . ~ f". -.. -.... ;¡ S:A':': i·o ¡.&T~':'Cë: ..: c.c " " , C.Q 1.S7 lGC.C .. . . .. P::Rh'.:SS":ON fOR RELEASE: 1 . . . ?armission is hereby granted for the Bureau or Mines to release the· c!>ove data, 'together with similar data re:~se¿ by ..tr.<:: operators os pu·blic: information and as ports of a series of papers on anofyses of sases from. various fiekh. staNn. or regions. .. COMPANY ~ BY. . ..... TITLE . . PET4:W:s ~;;~035ªB # 12 July 24, 1975 From: Officer in Charge, Naval Petroleum Reserve No. 4 To: Director, Naval Petroleum and Oil Shale Reserves Subj: NPR No.4, Crude Oil Analysis Enol: (1) Copy of M. D. Fishburn ltr Ber 408 of July 21, 1975 1. I am favorably disposed tm~ards the crude oil analysis suggested by Mr. Fishburn and recommend that the analysis be funded and undertaken. Terrence J. Woods copy to: Maurice Fishburn James Dowden James Harris R. Simonson . . DEPARTMENT OF THE NAVY NAVAL PETROLEUM RESERVES IN CALIFORNIA POST OFFICE BOX II, TUPMAN, CALIFORNIA 93276 TELEPHONE (TAFT, CALIF.) 765-4181 N-3 MDF:bds Serial: ,¥,ì ~ JUl 21 1975 From: To: M. D. Fishburn Lieutenant Commander Terrance Woods, Officer in Charge, NPR No. 4 Subj: NPR No.4, Crude Oil Analysis Enc1: (1) Letter from Mr. Russ Simonson to M. D. Fishburn dated 30 June 1975 (2) Letter from Mr. Irv. Tailleur to Mr. Simonson dated 28 May 1975 (3) Letter from Mr. Tailleur to Mr. Koch dated 1 March 1974 (4) Letter from Mr. Koch to Mr. Tail1eur dated 13 May 1975 (5) Pencil notes from Mr. Koch 1. It is recommended Navy proceed with the analysis of the crude oil samples from Navy's South Barrow No. 12 well as outlined in enclosure (1). It is recommended GeoChem do the analysis since samples are in Houston. Estimated cost of the study is approximately $200. 2. Enclosures (2) through (5) indicate considerable data can be ob- tained from crude oil analysis which may be useful in our future ex- ploration efforts. It would be expected Simpson Crudes and Uimat Crudes to be different. It is surprising, however, that Fish Creek oil is similar to Prudhoe Bay oil. Maybe it is true that the oil in the Sadlerochit Sand at Prudhoe Bay was generated from overlying Cretaceous Shales. 3. It is important that Navy continue to work with existing data avail- able from the wells in order to improve the understanding of the geologic framework on the Reserve. ~d~ 11(~~4~1N Copy to: S. o. Patterson, Tetra Tech{~;/& ðæ~ RECEIVED ~,·tUL 24 1975 NA VPETRES¡ ALASKA , , ""''''''''':''''''''''.'1.·. ~--':~;·t Hrr¡~ U~ . . -.l TETRA TECH, INC. .D.. POST QAf< pI-ACe SUITE 266 HOUSTON. TEXAS 770ê'7 TELEPIoIONE (713) 629-92BO June 30, 1975 Mr. Maurice Fishburn Naval Petroleum Reserves No. 1 P. O. Box 11 Tupman~ California 93276 Dear Maurice: Enclosed is a copy of Mobil I s analysis of the Umiat and Simpson No. 1 crude and Simpson seep oil which were received from Irv Tailleur of the USGS. There are also some handwritten notes, presumably by Tailleur on oil analysis results which indicate the following: (1) Simpson No. 1 well crude is similar to the oil from the seepage. (2) Umiat crude is different than Simpson oil. (3) Fish Creek crude is not close to either the Simpson or the Umiat oils. The Mobil letter also indicates that the Simpson and Umiat crudes were derived from different sources. The other inclusions with Tailleur I s letter were the results of paleontology studies by Imogene L. Doher of the USGS on the S. Barrow No. 12 well and the Wiggens (Standard Oil Co. ) study of S. Barrow No. 3 well. In return for this material and giving us samples on ot4er wells, we have agreed to give them the Anderson and Wilcoxon report on S. Barrow No. 3 and No. 12 wells. I have received two quart bottles of crude from the S. Barrow No. 12 well. It is suggested that we have them analyzed by Mobil, GeoChem, or some other laboratory. Paul Cernock said a complete analysis would be about $170. 00. Please let me know of your ideas on this matter. Very truly yours, ~L~/I' ' '-/ / /5<-.I~?,;:e-~ . R. R. Simonson RRS: el Enclosures cc: S. O. Patterson CORPORATE OFFICES . 630 NORTH ROSEMEAO BOULEVARO . PASADENA, CALIFORNIA 91107 (213) 449-6400 ¡5/Vc,¿., PJ UNITED STATES DEPARTMENT OF THE INTERIOR . - 01,9"15 JUn 2· II . GEOLOGICAL SURVEY Branch of Alaskan Geology 345 Middlefield Road Mertlo Park, California 94025 May 28, 1975 Hr. Russ Simonson Tetratéch, Inco 3700 Buffalo Speedway Suite 902 Houston, Texas 77006 -~ Dear Russ: Enclosed are }fubil's analyses of Simpson and Umiat oils and Silber1~g's formal identification of Triassic at 2238.5, SBl2. In addition to the dissimilarity noted in his letter, AI Koch mentioned on the phone that neither resembled Fish Creek oil. As you'll recall, I relayed that Amoco found Fish Creek similar to Prudhoe. Probably the can of Fish Creek oil will pour soon and I'll get, on our way north, a sample of our own for Mobil's and Claypool's analysis. Talked to Wiggins an hour after he received the processed samples from Barrow 3. He found the slides just above and just below the interval (26)r-75) with mud and rock fragments bearing Jurassic and Cretaceous microfossils to be essentially the same. Despite some lithologic identity with younger beds normally overlying, these rocks seem to be in order and preliminary assessment suggests that drilling not geology produced the anomalously younger rock fragments. These samples do not test, however, the possi- bility of repetition of the pelletal oxidized beds and Monotis-bearing limestones farther down the hole (~7 3ù ). . Wiggins said that the dinoflagellate assemb~ages were the finest he had seen from Alaska and deserve formal description. Apparently J> limy beds are not often processed even though preservation in a calcareous matrix is sometimes best. I said I would re-sample bed-for-beå the Barrow 3 cores we have stored in Fairbanks on my way to the field.. We can expect to have a definitive study of those w:i.thin 6 months and Wiggins and I will publish ~ discussion of the biostratigraphy subsequently. Surprising how valuable the cores have been. Makes worthwhile all the sweat we invested in them.over the years. Incidentá1ly, ~'¡iggins pointed out that the "maturity" of the carbonaceous, organic material was low, about 2 or 2.5 on the usual scale. Suggests that the rocks were buried no more than 10,000 feet over the eons. £,uc,L.. ~ ',y ... -'.... . . The Navy's apparent shift with respect to the field party is a bit disappointing. I may have to give up on the order for color infrared photos from Standard and the $l~OOO S'1W I was planning to slab the new cores properly. However, my agreeing with yours and Maurice's feeling that sàaring the field studies would help your objectives was not conditioned by financial participation at the outset. After all, each of us is responsible to the same trust--public or country interest--and I feel obligated to help as much as I can. Financing is a practical or political factor tha~ does not alter the geologic needs. Obviously, the chance to look at Brady in the field is essential to your thoroughness. We will look at it anyway and should be able to give you nearly as long a look as you'll need with- out detracting significantly from our work. As I said on the phone, others might have different Op1n10nS but I see only some sort of Navy not private company designation as a requirement for your joining us at Drif~~ood for a few days. I hope that can be arranged. Regards, J-,--- Irvin L. Tailleur Geologist Enclosure ~ ,~ "' 2 .. . . Sranch of Alasbm Geology 345 Middlefield Road Henlo Park, Califonúz. 94025 June l:. 1975 Imogene 1.. Doher Paleontology & Stratigraph.y B.ranch U .5. Geologic.Ell Survey Federal Genter Denver. Colorado ·80225 Dear Imogene: PoUen ratt4-ns from the know 12 samples '-1i.S e. happy surprise. I vould like to experiment to see if the s~s c.ont1n.uas dOW""..L.:.~le. Enclosed are cnts fron litbs in oil smld thtlt look to ae ëkO!;t like those yie.ld1...'1.g pollens. Sil~erl1ng' 6 enc.lose-d iden~·Hic..a.tio::l puts a. Triassic. or older megafossil age on. th~ deeper s8!:Iples. Yould you 1rlnd also lookh~~ at the po1.le:.l slides Dick has from core:s c.ut in the old daya! I'll list the þertinent ones at the end but the. prohlen1 _ is tœage of the }jarrQt~ gas sand in SB 2 [t 4. Ralph st:i.cl'..s to h:ts ~1.~dlc· Jurassic. 1.dentification of the ~te a.t S3 2. P"nysiCÆ:Ùly a:-~d siulply, thet sand should hø.ve been deposited ~th the intervús of SB 3 end SE 12. ãergEtttist/LoebI:Lch saw soœe Early Jurassic aspects to the fcn:nms il\ S13 2 & 4 BO .you:r comparison could be decisive.. If either the old or new s.amples bave pollens ~ others. consu1t&tion with Virgil \ti'i..gg-:...ns (SOCAL, 320 ¥.£rket Street, Ssn Fr2n.cisco, Ca1.i.£. 9¿1l1; Tel. 415-894-4195) ttrOhably ~ld hc.1p. We do not n£VD. P:::l.:.d.ss:icn to share the Ne:vy's new Wë!1l 60 you shou1d keep that W!t__r-'~l a little t:i.ght until I get word ~f Ne.vy's rele.a.se to you. ifi.ggins, s.s you may know, is preparing Co publish his eva.lus.tion of t.~e. open-f:tlcl slides from the old eçlaration. Finding identifiable weeds and seeds is great; hope it is just a prelude. Tb.&n1~s . ITVin L. 'failleur Geologist Enclosures cc: ~ss Simonson, Houston, Texas S-/lo/, t; ,oJ..ð..('O Ife~o-r"" lv..~ .$'- ;Z ()oo.¡ I ,)., 0,;29·;).. ~C>~;¡'7 .20 ~ /. ~ Sß ~ Jeç. _ /' ' //e ~. .$ I , /.?. . ¡Jct¡ þ ,/ ¡)(}"~ ,P'V~ 0- ~ÞðJ s.. "'I'/~-r T'o &I c... '" ¿co,. tZe c/ if- <.Þ ,.. . $o....e Pe .,.;,-,. f) PÞO vf1'''' . s ~£..., t/t" ~ ~ /c. 'l ~·.uJ"4 ~e/,pcltl'...,·c ~ bulk /.;rp- -.,.r/~/," hu 7Y"DS~N;. £ ð .-IV' tit<> . "../ e ~7. ¡;...J G-re-I- 'J" <-c. ,- .. s: r 'c. (.t!fto........,¡ -f c> C4 _. c/, Se.:¡I',o;. . '.. 'xx . 1 AA . -ST".'IG"~IC ...,..., ANal Upper T..iassic ......" A-75-1 Gf........" Point Ba....olll Alaska _GION "OCA\.ITY a... a. No ..·the..n (II)&O""''GU OAtI OR AIIIA Ba....olll A-4 Quadrangle eaec::eIWO 02/13/75 "'\ IUIIiOI () J "A'fW 'OISIU Ma..ine Mollusks Of' ___It Co_pLata """"'ID ~n .y I. L. Ta i ll.ur, Alaskan a..anch . UIOIImt 05/06/15 ..IJIOItT Nichols Silb...ling "'I'AIIIO a., K. H. and H. J. Sp.ci~.n is froB South Barrow Test Well No. 1Z. tat. 71 dags. i4 Qin. 18 sec.. long. 156 dags. 20 min. 06 s.c.. T. 22 Mol R. 17 W.. Saction 23. DEPTH IN FEET 2238.5 HALO.aIA of cf. H. ORHATISSUIA group . Age: late Ka..nien - early Norian Speciaen will b. added to Paleontology and St..atigraphy ..eference coLlections at MenLo Park. a . J(~. /VlvtA k. M. Nfchols .,,' ., N(wt.-- tJ. J. 51 lberling ~ '..~, RfPORT NOT TO BE QUOteD OR P~RAPttRASED IN PUlSlICATION WITHOUT A PINAL RECHECK 8Y THE PU HI >J ;:)1 C 1.\' f'~.':' <;LUt"(iH \'\¡I" m¡...u':C:H .. ,. . . . : ~raneb of Ala8an Gotology 345 Middlaf iald ao.d Menlo Pa~k, Ca.l1fomia 94025 Karch I, 1974 Hr. A. tocb Mobil Oil CorporaUoa P.O. Box .5444 Den.,ar. CÐlb\ - 80217 Dear Al; Enclosed an two crude.8&!r,)le8 broaght dmm by Florence Weber. The bottle of S1.!;pson 011 1.a orlg1na1 and all there was. Umiat-Ruby 11 (offic.i.al1,. thdat 4,p. 71, Prof. Papa 305-B) was in 8 metal CI!U2; an~Hr p&rt bottle r~:ftla. There was a eau of Fiah Creek that would not pour in the -50·p temperatu%e. It will have to wait on warming or break up-. /' I will look tornrd to your a.tta.lYH~. Hopefully, you will be able to furnish finserprints of other o11s to which p~b118hable comparisons can be cade. Perhaps 18"1erin§ your 1:I.S%1qe:tent: into pcmitting 8 jointly authored nou is strategj.c,A'l'PIT (at this point in time). 1 suggtst you- a190 c~.ec:!t with Harry Tourtelot (GS-Deuver) and Ids coraputer full of oil shale L~YSes. Cord1å11y. Irvin..· L. Ta1l1eur cc: Dir. RF ACG-MRP..F \. Tailleur File (AGß) REAding ILTailleur/vvj . , . £Þ..;c.L- , -@) . Mobil Oil Corporation . P.o BOX 5444 DENVER COLORADO 802:7 May 13, 1975 Mr. Irv Tail leur . U.S. Geological Survey 345 Middlefield Road Menlo Par.k, Cal ifornia 94025 Dear I rv: , Here, at last, are the gèochemical data on the Umiat crude and Simpson crude and seep oi I which you sent us in March 1974. Since there was no rush at the time we discussed these analyses, I submitted the samples with a low . priority. The long turn around time reflects the priority and an overload at our Field Research Laboratory. If we submit more NPR #4 samples, I can get much quicker results by giving them a higher priority, probably a few· weeks to one month. We have ~ssigned Mobil identification numbers 4344 (Umiat) and 4345 . (Simpson crude) and 4357 (Simpson seep) to each of these oils~ Geochemical data on the attached table includ3 chromatographic composition, API gravity, .).nfrared ratios, and whole oi I CI values. .The infrared ratios and C'3 measurements are usually of greatest value for correlation. The Simpson seep and cf~de ~ppear similar, but as shown in Table composi- tional, spectral and C differences exist between the Simpson oils and the Umiat crude. These differences suggest that the Simpson oi Is were not derived from the same source as the Umiat crude. If YO~3have any questions concerning the data, please feel free to cal I. The C measurements are given in Mobil's ppm and also the more commonly used Chicago "P.D.B." scale. I certainly apologize for the delay in getting these data to you and can assure much shorter turn around time in the future. .., Sincerely, (ftfl¿. ..... .. ;.,Î': ' . U"'~ , .. ".." A. J. Koch . AJ Kn n .. Attachment '. . ..-.-.-,,-, "..-.."'. . . -_. ......--_.... --~--_. q Eµ6i: @ "\ . . þ TABLE I SUMMARY OF GEOCHEMICAL DATA .CRUDE OIL AND SEEP SAMPLES: NORTH SLOPE AREA, ALASKA e .J !...Jiydrocarbons ! I nf rared Ratios· CI3 .sC13 Sample Type and/or Source Saturated Naph.-Aromatlc Asphaltic 12.3u/13.l\u n.4u/13.9u (ppm+IO,OOO) =-P.D.B. ~. FRL No. Seep, Simpson Area, col- 50 36 14 1.09 1.19 801 -26.30 200 4357 lected by ·U.S.G.S. 1946 Crude, Simpson all Field, 47 37 16 0.96 1.19 600 -26.40 210 4345 Naval Pet. Reserve #4 ~, Umiat Oil Field, 63 31 6 0.94 0.93 615 -27.05 350 4344 Well: Umiat #4 . *The 12.3u/13.4u ratio Is determined by the IntensitIes of absorption of two bands observed In the spectra of relatIvity pure mixtures of heavy aromatic hydrocarbons. The 13.4u/13.9u ratio Is derived from two absorption bands In the IR spectra of the total stabilized sample. The 13.4u band results from IR absorptIon by aromatIc structures, while the 13.9u band results from IR absorption by straight chain (par~ffln) structures. This ratio can be used ðS a rough Inverse Indicator of the parafflnlclty of a gIven oil sample. . '7._ ...s ..- ~. .,-.- A 1--·· .- ..--. - ..- -~.. ..-.-_... ._- .... - .... .~. . ..- .. --.. -_. '. ?~~-:-7~&r .__J-~_ú~~_._____._ . ., . '¡ I ."¡ - - --.-. _. -. - .,. -. -- . _._... ~' ~L-é¿j ....---_.. -._.~ - ~.-- . . - ----..-... . I' C.~ -. -..-----..-.---. ". ._. - ..- --- ... -- ...... .------ {~~._.._._~~..._.(..~?- i --_...-- - ..- - ... /.._- --- -- _.$~-~. ---------. ______... .__ _.._ ...n . - .. .... ...'., -_. - .V ~___ -.:Jf;;:-t.-_.-2/~- .--,'...--_..----- - c~;iÄ ~j¡ /11 .'"" --...-_._-_._-_.-~-----.._-- ---..". --.(.--.. ------- - .... - -- pf~'C ~ C¿4.. ~ ..eÝ~ -_.. -- --. -------. , - ~ _..- ¿¿,.,/"""~ . 1""-... - ,; 7 --_._-~~ -~~ ~/:".-?- &·fL~~J , --r~.:? C~¿.-. ~&i» .... __:::~-~~~-~u-~~--¿=-:~u .~ ....__. It:.L~: ._s;-~__J~-çc.-.~r._.___. __ _ n' - Id~:i:c'-<!~----::Y . ~J-~--- ., {~I .-- ..~~~--~ :2..-7(..¿.('..~t7"---- I~~-._ k->_¿~~__ '-~~~"7 ?l? ,ð"G'" - -.-. ._. .."- -,p~-1-."~- .~.- J-..ý~.f._. ~UL-.!1 '-.J r-'~-» ~,c..t.L:__ 1- () /. tt,.A..IÎ _. ~_ "..., ..t:.I:!.-_./;C,t.~. /1' ---- ..- - - . -_. - .- ----- .-- .~... ___ __ _. ._____. - __ ...___ _. ._p _n_'. --.----- ,...------ ----------..-.-.- .-..., -. -.- - -- ..--- --. -' . ..--- ----. -------- _.. ---.......-..-.- ..-' --- -- ."-' U·__.. ___ "... .________...._._ ._..___. __ - _n_ _ --- -._--.. ... . -- -_.._- --- -- -.-----. .,.-.. _... "'_Uo ___ _.__.- __ ..__ . - ... -_. ._.__·_u___ __'_0. _..__ --_..-._" --- --.-. . ... ---.... ._---- -..---- .---- --..----- - _.-. ---- ..-.... ---- ....------ e .._____.__.._ _._.___~. __...__....._____.., ~._._ _.. ___._. __.__ -.._---.____0-- .--'. .------. . - - - ---- -.---- ---_..... ---.---.---. --------.---.------ .------ .-- -.--------.-----.. -.._" -~.- _._. __._ _._.,_ .__.__..___. ,._ '·.H~ .. ----.--- .~._._..... ;. ___u_ _.__________..... _....__ ___ __~____ _d___ -------- ._._-,--~-~. ..-- .-' --.----." - ._~-----_.- ....- . -~_.._.. ¡ '- -...._- ---- .'-<------~._-.. -- ------¡---- . -. -..---- -"-.. .. u_·_.._ _ .__~ .'- ~._- .---,.:.---.--,..------- ..r-------..-.-- .. . , ---------- --_..:. -. --- --_.. - --'---'-- - ..-- ------.- ---- .-. eµGLO, ~j . . j//ÔÖ,1 SfJ'I'Z. "fW - f :-n: TETR.... TECH,INC. ..e"4 POST OAI( !I=ILACe SUITe 26S ~OUS~ON.TEXA.~77ca7 TeU!_ONE (713) ea&·saso 15 October 1975 " Mr. Maurice Fishburn Naval Petroleum Reserves No. 1 P. O. Box 11 Tupman, California 93276 .j NAVPETRES ðL' 1<: .~'V', ' --, , ~ ~" . ~"":¡' '~';;A~H Dear Maurice: Enclosed is a copy of the GeoChem laboratory analysis of crude from NPR-4 South Barrow No. 12 well. I had asked Paul Cernock for analysis he m.ight have of North Slope oil, especially Prudhoe Bay oil. He said that was confidential information he could not give out without the client's permission. Therefore, we have no other GeoChem analysis to compare it to. We do have the Mobil laboratory analysis on three oils; the Simpson No. 1 well, the Simpson seep, and the Umiat crude which are herein enclosed. A comparison of the Itpercent asphaltic" shows that the 14.60/0 of the S. Barrow No. 12 compares favorably with the 14% of the Simpson seep and not too far below the 160/0 of the crude from NPR -4 Simpson No. 1 well. The Paraffin-Naphthene (P -N) content for the S. Barrow No. 12 well of 37.2% compares favorably with the 36% for the seep and 37% for the Simpson well samples. I am not sure this is a valid comparison, how- ever, because the Mobil values are labelled, "Naph. -Aromatic" and not "Paraffin-Naphthene" of GeoChem. Again, the total I1Asphaltene" and "Paraffin-Naphthene" of GeoChem. is 51. 8% which may correspond with the 50% of "Saturated" hydrocarbons of Mobil's report. Beyond these comparisons, there is little that can be done without getting further information. Mobil has offered to run the South Barrow No. 12 oil at no ·cost to us. Husky has made the same type proposal to be done a.t'their Cody, Wyoming refinery. ,It is recommenÆied that we split th·e half -:gallon sample of S. Barrow No. 12 ~oi1 and send patto! it to Mobil and part of it to Husky. As you know, it ~:will require sonie authorization on Navy's part before these samples carl be : sent out. Very truly yours, C7u~~~ R. ~on Chief Geologist RRS:el cc: LCdr. T. J. Woods, OiC / J. Lagler, Or,JPR J. W. Dowden, Husky Enclosures 2 COl=lFOORATE OFFICES . 630 NOI=ITH ROSEMEAO eOUL.EVARO . PASADENA, CALIFORNIA 91107 . (213) 449-6400 ¡. .~ .- - ,-. =-, R T[7":. ., -- ,-, ~ :-........ ," i 0""'· J.. . '__. GEOCHEMICAL ANAL YSES SOURCE ROCK EVALUA TION CRUDE OIL CHARACTERIZA nON CRUDE OIL-SOURCE ROCK CORRELATION GEOCHEMICAL PROSPECTING 1143-C BAITTMCRE ROAD . HOUSTON, TEXAS 77043 . 713/467-7011 October 14, 1975 Mr. Russ Simonson Tetra Tech Inc. 4544 Post Oak Place Suite 266 Houston, Texas 77Q27 Dear Mr. Simonson: Please find enclosed the results of the organic geochemical analyses carried out on a crude oil sample (GeoChem :if 529-001) obtained from the South Barrow:# 12 Well located in the Naval Petroleum Reserve :/I: 4. The geochemical analyses performed on the oil sample comprised detailed C 4 -C7 gaso1ine-raDge hydrocarbon analysis (Table I)s C15+ quantitative liquid chroma- tographic separation (Table I), C1s+paraffin-naphtbene (P-N) analysis by gas chromatography (Table I; Figure 1) and A. P.I. gravity @ 60°F (Table I). You mentioned in our telephone conversation that the oil sample had been stored in the plastic container for some time (four plus weeks) before arriving at GeoChem. Like'\Y"Ïse, ba.ctericide had not been added to the oil sample before shipment to Geo.... Chem. Fortunately, our analyses show that the aforementioned storage and ship- ment procedure has not had any apparent adverse effects (i. e. biodegradation, etc.) on the geochemical characteristics of the oil. The South Barrow :fI: 12 Well oil is defined as a moderately ma.ture, ~ood quality., para:ffino-naphthenic oil which has not undergone any apparent biodegrada.tion either in the reservoir rock or duriDg transport to GeoChem. Table I shows this oil has a moderately low percent Asphaltene (14.6%), a fair percent paraffin-naphthenes (37.2%), of which 81.3% are naphthenes, and a moderately low A. P.I. gravity of 23.9"'. . . l\Ir. Russ Simonson Page 2 The oil is defined as only·moderatelv mature because only a fair percent paraffin- naphthenes (37.2%) make up the total C1S+ fraction, because the Sat/ Arom ratio of 1. 51 in Table I is not significantly high, and because of the fair A. P.L gravity of 23. 90. The paraffin-naphthene hydrocarbon fraction displays a moderately mature to mature character in Figure 1. Notice the absence of any odd-even carbon preference of the normal paraffins greater than CZ3 (the presence of an odd carbon preference suggests immaturity). The paraffin-œphthenes are also skewed to the left, or the lighter C15 to CZO' more mature hydrocarbons. The fine-gra.ined rock which sourced thè South Barrow # 12 Well oil could be iden- tified by geochemically analyziDg fresh cuttings from this well. The detailed C4-C7 gasoline-raDge data. and C1S+ paraffin-naphthene (P-N) gas chromatograms of the source rock would be very similar to those obta..ined for the oil in this study. The most important correlation parameters for crude oil-parent rock identification are: 1) similar 2-metbylpenta.ne/3-methylpentaœ (2MP/3MP) ratios, 2) similar isopentane/normal pentane (iCs/nCS) ratios, 3) similar cyclohexane/methylcyélo-- pentane (CH/MCP) ratios, 4) similar methylcyclopentane/metbylcyclohexane (MCP/MCH) ratios. and 5) similar C15+ paraffin-naphthene gas chromatogram patterns . I will be pleased to discuss these results with you in greater detail,. if you so desire. If I may be of any further assistance, please advise. Yours very truly,. .<'1 ~ ./ì ;l-"" f:-j I ./':, . a..¡,..-.. --.-I ,~ "..-:-" ; Paul J. CeIÎ10ck Chief Geologist GEOCHEM LABORATORIES, INC. ~ 11 UJ-t.-~~ PJC/nsf Enclosures . Tab 1 e I . Detailed Compositional Data for Crude Oil Sample No. 529-001 GROSS OI~ COMPOSITION % C15+ OIL COMPOSITION % less than C1s+Fraction 13.8 Asphaltene(ASPH) 14.6 Paraffin-Naphthene(P-N) 37.2 C15+ Fraction 86.2 Aromatic HC CAROM) 24.6 100.0% £1 uted NSO 7.1 Non-eluted NSO 16.5 A.P.I. Gravity @ 600 F 23.9 100.0% DETAILED C4-C7 COMPOSITION % DETAILED COMPOSITION OF C15+ SATURATE HC % I sobutane . 1.5 nClS 7.9 n-Butant! . 5.0 "C16 10.8 Isope"tan~ 11.0 "C17 11.3 "-Pentane 8.6 ip-C19 5.9 2. 2-Dimethylbutane 1.3 "C18 10.3 Cyclopentane 1.5 ip-C20 5.4 2. 3-0imethylbutane 2.4 "C19 9.2 2-Methylpentane 7.2 nC20 8.2 3-Methylpentane 4.9 nC21 7.0 n-Hexane 8.4 nC22 6.6 Methylcyclopenta"e . 5.8 nC23 5.3 2. 2-Dimethylpentane 0.6 oC24 3.9 B~nzene 2.2 nC25 2.8 2, 4-Dimethylpentane nC26 1.9 2. 2, 3-Trimethylbutane 0.6 nC27 1.3 Cyclohexane 6.6 nC28 0.6 3,- 3-Dimethy1pentane 0.8 oC29 0.2 1, l-Dimethylcyc1opentane 1.2 "C30 0.1 2-Methylhexane 3.0 nC31 0.2 2, 3-0imethylpentane 1.8 nC32 0.1 1, c-3-0imethylcyclopentane 1.3 nC33 3-Methy1hexane 3.3 l,t-3-Dimethylcyclopentane 1.4 1.t-2-Dimethylcyc1openta"e 2.4 3-Ethylpentane 0.9 ~ Normal Paraffin 16.4 n-Heptane 5.4 1, c-2-Dimethylcyclopentane 0.9 % Isoprenoid 2.1 Methylcyclohexane 8.4 % Naphthene 81.3 To.l uene 1.5 Sat/Arom 1.51 MOLECULAR RATIOS Asph/NSO 0.62 2-methý1 pentane/3-methyl pentane 1.48 CPI" Index A 1.02 isopentane/n-pentane 1.30 CPI Index B 1.12 cyclohexane/methylcyclopentane 1.15 ip-C¡9/ip-C20 1.08 methylcyclopenta"e/methylcyc1ohexane 0.69 16 17 15 l / ~ i .. . FIGURE 1 18 529-001 19 20 21 a ' 22 .. b 23 24 25 L r : 'I.i "' : \ !~ ¡ i --. 1 26 , I ~ ~ - 27 I ~~ ~j ~ NAPHTHENES MATURE CHARACTER 28\ 29 '" 30 31 32 . . FIGURE 2 a 18 . 19 STANDARD 17 20 21 No. Denotes n-C Paraffin - n a = ip-C19 = Isoprenoid Pristane b = ip-CZO = Isoprenoid Phytane 22 , , 23 16 24 b 25 15 26 I -I 27 ~ J ~3132 I ~I ~_ . t--1 ' ,.. oJ oJ v I---' NAPHTHENES . Mobil Oil Corporation . P.O. BOX 5444 DENVER. COLOI'IADO 8Q2~7 May 13, 1975 r-tr. I rv Tai Ileur . U.S. Geological Survey 345 ~;1i dd I ef i e I d Road Menlo Park~ Cal ifornia 94025 ..."'.... '. Dear I rv: Here, at last~ are the geochemical data on the Umiat crude and Simpson crude and seep oil which you sent us in March 1974. Since there was no rush at the time we discussed these analyses, I submitted the samples with a low priority. The long turn around time reflects the priority and an overload at our Field Research Laboratory. If we submit more NPR #4 samples~ I can get much quicker results by giving them a higher priority, probably a few· weeks to one month. We have ~ssigned ~bbil identification numbers 4344 (Umiat) and 4345 (Simpson crude) and 4357 (Simpson seep) to each of these oils. Geochemical data on the attached table includ3 chromatographic composition, API gravity, _infrared ratios, and whole oi I Cl values. The infrared ratios and CI3 measurements are usually of greatest value for correlation. The Simpson seep and cí~de 'àppear s i mil ar, but as shown in Tab I e compos i- tional, specti-al and C differences exist between the Simpson oils and the Umiat crude. These differences suggest that the Simpson oils were not derived from the same source as the Umiat crude. - If YOV3have any questions concerning the data, please feel free to cal I. The C measurements are given in Mobil's ppm and also the more commonly used Chicago "P.D.B." scale. I certainly apoiogize for the delay in getting these data to you and can assure much shorter turn around time in the future. Sincerely, I(kÚ .~ '- A. J. Koch . AJ K/ L n . . . .----: - ... - Atta.chment .. ,-- - -- - -. ..... .. ___.h , , , , . . ~ . TABLE I SUMMARY OF GEOCHEMICAL DATA CRUDE OIL AND SEEP SAMPLES: NORTH SLOPE AREA, ALASKA !l!Y_drocarbons ! Infrarod RatIos· CI3 6Cl3 Saml1le Type end/or Source Swturotad Nil()". -AroR1at I c Asphaltic 12. "!Ju/ ïI:'"t1u l3:4üiTI.9u (1)l1m"", 0,000) API Gr. FRL No. =-P.D.B. Seep, Simpson Area, co 1- 50 36 14 .09 1.19 801 -28.30 20° 4357 lected by U.S.G.S. 1946 Crude, SImpson 011 Field, 47 37 16 0.96 1.19 600 -28.40 21° 4345 Naval Pet. Reserve #4 Crude, UmIat 011 FIeld, 63 31 6 0.94 0.93 615 -27.05 35° 4344 Well: Umiat #4 e *The 12.3u/13.4u ratio Is determIned by the IntensItIes of absorptlòn of two bands observed In the spectra of relatIvity pure mixtures of heavy aromatic hydrocarbons. The 13.4u/13.9u ratio Is derived from two absorption bands In the IR spectra of the total stabIlIzed sample. The 13.4u band results from IR absorption by aromatIc structures, while the 13.9u band results from IR absorption by straight chaIn (paraffin) structur~s. ThIs ratio can be used as a rough Inverse Indicator of the paratflnlclty of a gIven 011 sample. . . CORE LABORATORIES, INC. Petroleum Reservoir Engineering DALLAS. TEXAS November 5, 1974 u.s. Navy c/o Officer-in-Charge Naval Petroleum Reserve No.4 Barrow, Alaska 99723 Attention: Lt. Commander R. V. Shafer Subject: Reservoir Fluid Study Naval Petroleum Reserve No. 4 Barrow No. 12 Well Barrow Gas Field Alaska Our File Number: RFL 74268 Gentlemen: Two subsurface fluid samples and one wellhead gas sample were collected from the subject well by a representative of North Star Engineering and forwarded to our Dallas laboratory for a reservoir fluid study. This report is a result of that study. Upon arrival to our laboratory, room temperature bubble point pressure was measured on both subsurface samples. Cylinder No. SS2l5, sampled at 2000 feet, was found to have a bubble point pressure of 880 psig at 74°F. Cylinder No. SS476, sampled at 1900 feet, was found to be saturated at 865 psig and 74°F. Cylinder No. SS215 was selected for the reservoir fluid study. A sample of the reservoir fluid was charged to a visual cell at the room temperature of 75°F. Since room temperature was higher than the reservoir temperature of 51 of., no thermal expansion was determined on the reservoir fluid. During constant composition expansion, the bubble p:>int pressure of the reservoir fluid was found to be 847 psig at the reservoir temperature of 51°F. . . u.s. Navy Naval Petroleum Reserve No.4 Barrow No. 12 Well Page Two Duringßifferential pressure depletion, the reservoir fluid liberated 119 albic feet of gas at 14.65 psia and 60°F. per barrel of residual liquid. The formation volume factor was determined to be 1.037 barrels of liquid at 847 psig and 51 of. per barrel of residual liquid. The gravity of the residual liquid was found to be 25. 3e API at 60°F. The vi scosity was mea sured at the reservoir temperature of 51°F .;------- and at pressures ranging from well above reservoir pressure to atmos- pheric. The viscosity of the liquid phase was found to vary from a minimum of 48.89 centipoises at saturation pressure to a maximum of 118.14 centipoises at atmospheric. Separator tests were performed at room temperature and at separator pressures of 30, 60, 120 and 200 psig. The results of these tests along with the measured specific gravities of the gases flashed through the separator are presented on page six. The hydrocarbon analysis of the wellhead gas including the mol percent of helium present in the gas is presented on page seven. A portion of the reservoir fluid was charged to low temperature iractiona¡ distillation equipment for hydroca.rbon analysis. The results of this analysis along with the properties of the heptanes and heavier fraction are presented on page eight. Thank you for the opportunity to be of service. Should you have any questions regarding these data or if we may be of further assistance, please do not hesitate to contact us. Very trulj yours, Core Laboratories, Inc. Reservoir Fluid Analy sis Pt7ltr.u--û P. L. Moses Manager PLM:RL:hm 7 cc. - Addressee . Company U. S. Navy Well Barrow No. 12 Field Barrow Gas Field CORE LABORATORIES, INC. Pet,oleum Reservoi, Enginee,ing DALLAS. TEXAS . Date Sampled County State PagA 1 of 11 File RFL 74268 April 11, 1 974 Alaska FORMATION CHARACTERISTICS Formation Name Mohr Sand Date First Well Completed Ma y 11 Original Reservoir Pressure 889 PSIG @ Original Produced Gas-Oil Ratio Production Rate Separator Pressure and Temperature PSIG. Oil Gravity at 60° F. Datum Original Gas Cap Elevation Total Depth Producing Interval Tubing Size and Depth Productivity Index Last Reservoir Pressure Date Reservoir Temperature Status of Well PressureG:~ºge Normal Production Rate Gas-Oil Ratio Separator Pressure and Temperature Base Pressure Well Making Water ,19~ 2150 Ft. SCF /Bbl Bbl/Day of. ° API Ft. Subsea WELL CHARACTERISTICS KB 26 2282 2197-2264 Ft. MSL Ft. .Ft. In. to Ft. RbljD /PSI @_Bbl/Day 889 PSIG @ 2150 Ft. Aprilll , 19~ est 510F. @ 2200 Ft. * 30650 N '~ BbI¡Day SCF /Bbl of. PSIA ÐfÐ Cut PSIG, o SAMPLING CONDITIONS Sampled at Status of Well Gas-Oil Ratio Sel:>arator Pressure and Temperature Tubing Pressure Casing Pressure Sampled by Type Sampler 1900-2000 Ft. Temporary Completion SCF /Bbl of. PSIG PSIG PSIG, North Star Engineering REMARKS: * Temperature estimate based on data from other wells in the area. . . CORE LABORATORIES. INC. Petroleum ReIervoir Engineering DALLAS. TEXAS Page File Well 2 of 11 RFL 74268 Barrow No. 12 VOLUMETRIC DATA OF Reservoir Fluid SAMPLE 1. Saturation pressure (bubble-point pressure) 847 PSIG @ 0.99091 51 OF. 2. Thermal contraction oioH @ 5000 PSI = V @ 51°F V @ 75°F - Compressibility of saturated oil @ reservoir temperature: Vol/Vol/PSI: 3. From 5000 PSI to 4000 PSI= 3.95xlO-6 4000 2000 PSI = -6 From PSI to 3.77xlO From 2000 PSI to 847 PSI = 4.60 x 10-6 4. Specific volume at saturation pressure: ft 3/lb 0.01811 @ 51 of. Th-. anal7æø. opinions or interpretations are baMd on observations and material supplied b)' the client to whom. and for wh08e exclusive and confidential use. this report is maile. The interpretations or opinions expreøøed repreøent the beat judgment of Core Laboratories. Inc. (a1\ errors and omisaions excepted): but Core Laboratori-. Inc. and ita officers and empl_ IUIIIUJDe no responsibility and make no warranty or representations as to the productivity. proper opera_ tion. or profitablen_ of any oil, pIlI or other mineral well or und in connection with which auch report is used or relied u1lOn. . . CORE LABORATORIES, INC. Petroleum Reservoir Engineering DALLAS. TEXAS 75207 Page 3 of 11 FilA RFL 74268 Well Barrow No. 12 Reservoir Fluid ¡i:;AMPLE TABULAR DATA PRESSURE· VOLUME VISCOSITY DIFFERENTIAL LIBERATION @ 51 ·F. RELATION OF OIL PRESSURE @ 51 ·F. . 51 ·F.. GAS/OIL RATIO GAS/OIL RATIO RELATIVE OIL PSI GAUGE @ LIBERATED IN SOLUTION VOLUME. RELATIVE VOLUME OF CENT I POISES PER BARREL OF PER BARREL OF V/VR OIL AND GAS. VNSAT. RESIDUAL ca. RESIDUAL OIL 5000 0.9831 98.33 1. 019 4500 0.9851 1.021 4000 0.9870 86.56 L 023 3500 0.9889 1.025 3000 0.9906 74.75 1.027 2500 0.9927 68.23 1. 029 2000 0.9945 62.23 L 031 1500 0.9967 56.57 1.033 1000 0.9990 50.70 1. 036 900 0.9996 1.036 847 1.0000 48.89 0 119 L 037 834 1.0023 828 1.0034 822 1.0044 816 1.0055 758 1.0203 700 53.46 15 104 1.031 683 L 0421 610 1.0748 567 1. 1187 550 59. 72 34 85 1.025 467 1 . 1 844 400 67.02 54 65 L 019 392 1. 2721 332 1.4040 262 L 6017 250 78.58 77 42 L 0.11.3 212 1.8609 154 2.2751 108 2.9302 86 102.41 104 15 1. 004 v = Volume at given pressure V.AT. = Volume at saturation pressure and the specified temperature. VR = Residual oil volume at 14.65 PSI absolute and 60° F. Th_ aual7Ms, opinions or Interpretations are hued on observations and material supplied by the client to whom, and for whose exclusive and confidential use. this report ia made. The Interpretations or opinions expreøøed repreønt the best judgment of Core Laboratories, Inc. <aU errors and omiøaiona excepted): but Core Laboratories, Inc. and ita ofrtcera and employeea, asøume no reøpolUlibility and make no warranty or representations .. to the productivity. proper opera- tion, or profttablen_ of any oil. ... or other mineral well or _nd In conneetio n with which such report is used or relied upon. . . CORE LABORATORIES, INC. Petrolellm Reservoir Engineeri1lg DALLAS, TEXAS 75207 Page Filp Well 4 of .1.1 RFL 74268 Ba rrow No. 12 Reservoir Fluid SAMPLE TABULAR DATA PRESSURE- VOLUME VISCOSITY DIFFERENTIAL LIBERATION @ 51 ·F. RELATION OF OIL PRESSURE @ 51 OF., 51 .F.. GAS/OIL RATIO GAS/OIL RATIO RELATIVE OIL PSI GAUGE @ LIBERATED IN SOLUTION VOLUME, RELATIVE VOLUME OF CENTIPOISES PER BARREL OF PER BARREL OF V/VR OIL AND GAS, V/VSAT. RESIDUAL OIL RESIDUAL OIL 68 o 4.0042 118. 14 119 o @60°F . ,996 = 1. 000 Gravity of residual oil = 25.3° API @60"F, v = Volume at given pressure VSA.T. = Volume at saturation pressure and the specified temperature. v. = Residual oil volume at 14.65 PSI absolute and 60° F. Thae anab'seø. opinions or interpretations ant hued on observations and material supplied by the client to whom. and for whOÀ exclusive and confidential use. thIs report is made. The interpretations or opinions expreased represent the beat judsment of Core Laboratoriea. Inc. (all errore and omiuioDB excepted); but Core Laboratoriea. Inc. and Ita oII!lcera and employæa. IUIIIUDI8 no reaponalbilit¥ and make no warrant¥ or repreaentatloDB as to the productlvlt¥. proper opera- tion. or proAtableneu of any oil. ... or other mineral well or øand in connectlo n with which such report is used or relied upon. . CORE LABORATORIES, INC. Petroleum RelertJoir Enginee1'ing DALLAS. TEXAS . Page File 5 of 11 RFL 74268 Well Barrow No. .1.2 Differential Pressure Depletion at 51° F. Pressure Oil Density PSIG Gms/Cc 847 0.8844 700 0.8875 550 0.8904 400 0.8927 250 0.8959 86 0.8998 0 0.9048 Gas Gravity Deviation Factor Z 0.606 0.9.1.1 0.585 0.926 0.578 0.944 0.575 0.963 0.585 0.985 0.682 Th_ &11&1,...... opinions or Interpretations are based on observations and material supplied by the client to whom,and for whose excluaive and confidential use, this report Is made. The interpretations or opinions expressed represent the best judgment of Core Laboratories, Inc. (all errors and omi88ions excepted); but Core Laboratories, Inc. and its officers and employees, assume no responsibility and make no warranty or representationa as to the productivity. proper 0pera- tion, or profltablenesa of any oil, gas or other mineral welI or sand in connection with which such report Is used or relied upon. · CORE LABORATORIES. INC. . Petroleum Reservoir Engineering DALLAS. TEXAS Page 6 of 11 File RFL 74268 Well Barrow No. 12 SEPARATOR TESTS OF Re servoirF1uid SAMPLE SHRINKAGE FORMA T ION SEPARATOR SEPARATOR SEPARATOR STOCK TANK STOCK TANK VOLUME SPECIFIC PRESSURE, TEMPERATURE, GAS/OIL RATIO-GAS/OIL RATIO GRAVITY, FACTOR, FACTOR. GRAVITY OF VR/VSAT, VSAT./VR PSI GAUGE · F. · API @ 60· F. FLASHED GAS See Foot Note (1) See Foot Note (I) See Foot Note (2) See Foot Note (3) (Separator) 30 74 109 8 25.3 0.9551 1.047 0.608 60 75 104 12 25.4 0.9548 1.047 0.598 120 73 94 23 25.4 0.9585 1.043 0.594 200 73 82 36 25.5 0.9610 1.041 0.596 (1) (2) (3) Sepa.I:.ator and Stock Tank Gas/Oil Ratio in cubic feet of gas @ 60° F. and J.4:. 65 PSI absqlute per ba-rrel of .stock tank oil @ 600 F. Shrinkage Factor5·lvRNsAT. is barrels of stock tank oil@600F.perbarrelofsaturatedoil@847 PSI gauge and . 0 F. Formation Volume Factor: VSAT./VR is barrels of saturated oil @ 84 7 PSI gauge and 51 0 F. per barrel of stock tank oil @ 60° F. 'l'beee aul,.... opiGioDS or interpretationa are haled on obøervationa and material supplied by the cHeat to whom, and for whose exclusive and oeafidential uae. this report is Jnade. The Interpretations or opinions ezpreøaed repreøent the best judlJlUent 01 Core Laboratories. Inc. (aU errors and omissions excepted): but Care Laboratories. Inc. and its officers and employ_. asaume no reBþOuibility and make no warranty or representations as to the productivity, proper opel'l\- tion, or profttableneu of any oil. gas or other mineral well or sand in connection wIth which mob report is used or relied uþOn. . . CORE LABORATORIES, INC. Pet,.ol,.,m Reswwi,. Engineering DALLAS. TEXAS Pasre 7 of 11 File RFL 74268 Company U. S. Navy Formation Mohr Sand Well Barrow No. 12 County Field Barrow Gas Field State Ala ska HYDROCARBON ANALYSIS OF Wellhead GAS SAMPLE COMPONENT MOL PER CENT -I C¡PM Helium Hydrogen Hydrogen Sulfide Carbon Dioxide Nitrogen Methane Ethane Propane iso-Butane n-Butane iso-Pentane n-Pentane Hexanes Heptanes plus 0.92 Nil Nil Nil 7.88 91. 45 0.56 0.06 0.01 0.02 0.01 0.01 Nil Nil 100.92 o. 141 0.017 0.003 0.006 0.004 0.004 0.175 Calculated gas gravity ( air = 1.000) = O. 590 Calculated gross heating value = 934 BTU per cubic foot of dry gas at ~ 4.65 psia at 600 F. Collected at 675 psig and 51 0 F. TheIle aualyses. opinions or interpretations are based on observations and material supplied by the client to whom. and for whose excJuaive and confidential _. this report is made. The interpretations or opinions expreIIIIed represent the best judgment of Core Laboratories. Inc. (all errors and omissions excepted); but Core Laboratories. Inc. and its otIieera and employees, 8II81UII8 DO responsibility and make DO W8.I'1'Bnty or representations as to the ProchJetivity. proper 0pera- tion. Or profitabJen_ of any oil. ... ór other inineral well or IIIUld in connection with wbich such report is used or relied upon. Company u.s. Navy . Barrow No. 12 Well . CORE LABORATORIES, INC. Petroleum Reservoir Engineering DALLAS. TEXAS Page 8 of 11 File RFL 74268 Fonnation Mohr Sand County Fielrl Barrow Gas Field State Alaska HYDROCARBON ANALYSIS OF Reservoir Fluid SAMPLE COMPONENT Hydrogen Sulfide Carbon Dioxide Nitrogen Methane Ethane Propane iso-Butane n-Butane iso-Pentane n-Pentane Hexanes Heptanes plus Cylinder NO. 55215 MOL PER ·CENT Nil Nil 0.56 22.34 0'.97 0.31 0.12 0.41 0.16 0.07 1.02 74.04 100.00 WEIGHT PER CENT DENSITY @ 60· F. GRAMS PER CUBIC CENTIMETER · API MOLECULAR @ 60· F. WEIGHT Nil Nil 0.07 1. 50 0.12 0.06 0.03 0.10 0.05 0.02 0.37 97.68 100.00 0.9055 24.6 315 Core Laboratories, Inc. Re servoir Fluid Analy sis P¡:JJ¡~~ P. L. Moses Manager Tbese analyses, opinions or interpretations are baaed on observations and material supplied by the client to whom. and for whoøe excluaive and confidential use. this report Is made. The interpretations or opinions expressed represent the best judgment of Core Laboratories, Inc. <an errors and omiuions excepted): but Core Laboratories. Inc. and its officers and employees, assume DO responsibility and make no warranty or representations as to the productivity. proper 0pera- tion. or profitableness of any oil. gas or other mineral well or sand in connection with which such report is used or relied upon. 02 > ~ cij :2 ~ ~ ~ 1/.1 > ¡::: :5 1/.1 II: 1.0 . CORE LABORATORIES. I. Petroleum ReseTVOir Engineering Page DALLAS, TEXAS File PRESSURE- VOLUME RELATIONS OF RESERVOIR FLUID Company U.S. Navy Well Barrow No. 12 Field Barrow Gas Field Formation Mohr Sand County State Alaska 4.0 3.0 I I I I' --;~~t=--~ t-- 11-= ~ ~ I '~T- =1=t 10, I' I I _~I III --+- I l ~.I 1- i II r I It' I~F¡--J-~i i ~II - . I: ¡ i --- II --+--1--- '1 I I, I +,-- I I I ---- ~t=t- - ~_-1 f -1-- ,---~---- ¡ ¡ I' I i I ¡ ¡, II" ¡I f ~,) I - f ¡ ¡ t I ' I ~--- I I II ¡:I-~ . I I II I ~ " -rr-t¡ \ I' I I I <'t Sa'c.l'at:.OL I --,----- · t II ' . . I --=--- I _l~_ ttF I ~~ó'o 2.0 - I I +-t I : o 0- o J - I i ¡ I I I 0.0 I 0 1000 2000 PRESSURE: POUNDS PER SQUARE INCH GAUGE 9 of 11 RFL 74268 ~-- -t, --HE- I -- -t-~- r.+1- II ¡ I I -- ¡- ~-- I ¡- ++- I 1- o I 3000 160 140 ..:¡ õ ..:¡ 00:: => Q ëñ w ¡r; c... o ..:¡ w ¡r; ¡r; 00:: ø:¡ ¡r; w p.. !- W W c... u æ => u Q ¡r; 00:: Q Z 00:: !- UJ Ò W !- 00:: ¡r; W ø:¡ :¡ UJ 00:: o 120 Q 100 Company Well Field --- 80 60 f' 40 j ( 20 o o . CORE LA80RATORIES. IN. PetTOieum Reservoir Engineering DALLAS. TEXAS Page File DIFFERENTIAL V AF>(ìH1ZA nON OF RESERVOIR FLUID u.s. Navy Barrow No. 12 Barrow Gas Field I I-~jj -1-lL' ¡ +-~+--=--~-++-+--rl ~- -- I' -- 1++ +-tt---t4-I.' I-I -----T-j-~r-~----11--=-j=-' ' I ' I ¡ I! I ! ¡ - +--t-L-- I - ¡-=--t- ------_. .------.---- -~======-f=-.--- '---T-t- --~utl-t=-- 1 --,-+ ~-j" +-±-t--+-t---- -- -==-=-u___~, --i'-Jr' -~ -¿-l+- ! I -J-______tt- --¡t!-J-~·-l ' I t 1 I I , ! 1 ' , I 1- I I ++¡--r--~~-1I,- - t -1---- ----- I . I --t- . ¡ t ! --- ~--=-...:j--+~= 1--1r+--=t+1+=~t· 8' .=-- ----î-+- ti ;r, ----d+ +- - -t--- , ""----~. i '1' t r' I ' -----t- ,-----...~ ' -+i'-,~-t±t±" --+rt-! I ,t, " ; - -- --~ ' I it ,-t--- --T ---.- -, =t- t -; - ,,--+-- - " ,-U-L~-+---i +-+--- , I ! I I I; I!! I ' :-r- t 'I, --t-r' -N -t-- '-~1--+-' t----- "!' '1' I' " I ! ¡ f ; i ! I I ; I ,~ ' _u_ --l¡-t-Lu+j-1--'---¡-'--+-r -t---i--+-+-· --;-+ tt ~, ~ I "II '" '4 'f-t ' ') ! I I I I 1--;- 1-;, ,! ¡-. , --11 I I II -'----¡---i-t----'--+-+,' _-t__+-¡- I J I ' ", ; ,I ' I Ii-I I I 1--'---+ - "-r- t --j-+--!- , I. I .----+---t--'- + , I ¡ ffi=i ¡ i I ¡ ,i ! I I' ! I I ---+--'-- --L-.¡ " nL -t--~-<---~- , I I I i i . "I; I I }'-rtttl' ¡'i , !-t-L,..-.;-+--r' 1- I I ¡ ~ I ¡ i: ¡I I " I ,I, r I I T~--ï- ¡ I '--tt f ~t-r+TT- ,-I !,~t¡ , . I -j---~--rtt +i--- 1---~-t- . I I I-t ---= ¡ I : I I ¡ I -------+--------. I ,~-++- ' , I I' , -L ¡ ----+ -+-+-t i--· . i I ¡ , "I ---r-- :t-LH- I I ¡ I I ¡ -± f 'F----+--- ~ I ,+-~ ,I . ~- --J;r' ..,--j..~,-- -~-++ ' ' ~~--- I, . f . - ,. t ! I . ¡ , t ¡ I ' II--=~- f' --~.~~~ll---¡¡ !-+- I : -I - , I " I _.c._-Tt__._j' __ " ¡ j. ¡ I ... " i I I -"------¡--- I ---------1 ! ¡ -- -------+-- rr--- -I--+- ------"-- I ,---1 Formaticn Mohr Sand ______ County _____ State Alaska < I- I I ' . I 11 t '-L T+--' -1- ~ ! '\ f -I \/ \ \ \ b \ \ \ 1000 ?OOO PRESSURE POUNDS PER SQUARE INCH GAUGE -10 of~ RFL 74268 ~ 3000 1.06 1.05 1. 04 1. 03 ø: > "- :> 1. 02 w :::E => ...I o > Q 5 o :¡ t..1 > ¡:: 00:: ...I W ¡r; 1. 01 1. 00 0.99 0.98 120 110 100 . CORE LABORATORIES. INC. P,etroleum Reservoir Engineering DALLAS, TEXAS VISCOSITY OF RESERVOIR FLUID Company U. S. t!TaVy Well BarÐow No. 12 Field Barrow Gas Field o I 90 .¡. (I] \ ¡.,.¡ (I] 2 ¡:: z 80 ¡.,.¡ {) ;>.; ¡.... ¡¡¡ 0 {) (I] :> 70 60 50 40 Q , Formation County State ') r \ \ \ \ Sa ;,"-rat~ClI_ __ / P::4I.Ubl..l't.' -- /- \ &,j !'SIQ- T~~ ..~. -~- \\/ ----- _._--_._~~_._--_. --+- ......_-, - -.- -------- ..-.--. --_._,- --'--- 1000 2000 PRESSURE POUNDS PER SQUARE INCH GAUGE . Page File Mohr Sand Ala ska 11 of 11 RFL 74268 // //~ I· 3000 I, 0'·111 P-ì (, \ ....".. SUBMIT IN DUP ,TE· (8,· . 'ther In~ ~t ru('tions on reverse side' STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE WELL COMPLETION OR RECOMPLETION REPORT AND LOG * oj¡, 0 WELL b. TYPE OF COMPLETION: :-óEW 0 wonle. 0 DEEp· 0 Wt;U, o\'r.R ES la. i:VP·F:,-Ò·' ,' W'~LL: GAS Iv1 .. ELL tKJ DRY 0 Oth~r PLUG 0 DACK "IF... 0 flERVR, Oth~r 2. NA.ME OF 01'ERATOn Director, Naval Petroleum and Oil Shale Reserves 3. A"DRESR 0.. OPERATOR Room 550, Crystal Plaza #6, Washington, D. C. 20360 4, LOCATlOS OF WE!.L (Reporl local ion clearlv and ill accordance with anll Slale requiremetlh)· At Rurfnee Alaska State Coord. System Zone 6: 6,305,300 (N); 695,850 (E); Umiat Prime Meridian. Approx 7P14'16.5"N At top prod. IDterul reported below 156020' 15.0"W At total depth (P. ' t;. 5, API NUMEIUCAL CODE ~ M .,;)0 - 02.3 - 2.000 ~ 6. LEASE DESIGNAHON AND SERIAL NO. ~ ~aval Petroleum Reserve #4 7. IF INDIAN. ALLOTTEE OR TRIBE NAME-1') N/A lCù 8. UNIT,FARM OR LEASE NAME N/A 9. WELL NO. 12 10. FIELD AND POOL, OR WILDCAT South Barrow 11. SEC., '1'., R., M.. (BOrrOM HOLE OBJECTIVE) Section 26, T22N, R17W 12. PERMIT NO. 13. DATE SPUDDED }14. DATE T.D. REACHED J15. DATE COM? SUSP OR ABAND. 116. ELEVAHONS (DF. HKB, RT, GR, '.':TCI' 117. ELEV. CASINGHEAD 10 MAR 74 16 APR 74 04 MAY 74 KB=26'MSL '. , # 18. TOTAL DEPTH, MD & TVDf9. PLUG, BACK MD & TVDr' IF MULTIPLE COMPL.. 121. INTERVALS DRILLED DY HOW MANY' / ROTARY TOOLS' . ~ CAULE TOOLS 2287 2088 . N A 2287 ft. 0 22. PRODUCING IN1'ERVAL(S). OF· THIS COMPLETION-TOP, BOTTOM, NAME (MD AND TVD)' 23. WAS DIRECTIONAL , SURVEY MADE South Barrow Gas Sand. Geological particulars on file with Of~icer in Char~e Yes j 24, TYPE ELECTRIC AND OTHER LOGS RUN DIL, FCD, CNL, BGT, HDT, BHC, CBL, BROX-ML 25. CASmG SIZE CASING RECORD (Report all strings set in w~lI) WEIGHT, LB/FT. ¡ GRADE ' DEPHr SET. (MD), HOLE SIZE 75# N80 160' 22" 51# P51 1067'. 14%" 23# 1884' 95/8" sx sx sx Permafrost 0 Permafrost 0 Perm., 270 sx Class "G" 0 CEillLNTING RECOll.!> AMOUNT PULLED 345 950 340 16" 103A" 7" 26. LINER RECOltD 27. SIZE BOTTOM (MD) SACKS CEMENT' TOP (MD! SCREEN (MD) SIZE 27/8" '11/:> " 2062 0 slotted 1884 28. PERFORATIONS OPeN TO PRõÍ>ucTÏ01of (Interv41, Rlze and number) TUBING ItE,COfID DEPHr SET (MD) r PACKER SET (MD) I~ 2053 N/A Never produced 2!J. ACID, SHOT, F~A::;TURE, CEMENT SQUJ:l':ZE, E.·TC. DEJPTIIINTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED 30, DATE FIRST PRODUCTION PRODUCTION CHœ<E SIZE {PROD'N FOR TES'f~ 71 APR 74 . FLOW, TUBING CASING PRESSURE CALCULATED OIL-BBL. PREss. . 21-HOUR RATE 'I ' . 31. DISPOSITION OF GAR (80ld, u.ed lor )uel, venled, elc.) WELL STATUS (Producing or ullut..in) . Shut in ··ìAS-MCF. WATER.-BBL. I GAS·OIL RATIO WATER.-BBL. lOlL GRAVITY-API (CORR.) o N/A TEST WITNr.SS~D BY I A. Crane PRODUCTION METHOD (Flowing, gas lift, pumping-size and type of pump) Never produced DATE OF TI:ST. HOURS TESTED OIL-BDL. I o GAS-MCF. I 360* 32. LIST 0" ATTACHMENTS 33. ì hereby CC~~d a n ~~o~nd corrc~t as det~rmlncd frum nIl nvnl1nblc rccurd" SIGNED TITLEr6fflcer J.n Charge DATE 2-28-75 R_V.Sh~fer.T~D CEC.USN *(See Instructions and Spaces for Additional Data on Reverse Side) Fonn I 0 - 40 I REV. 1- 1- 71 W L:i \\::J ~ y. U 1.:.. WJ U·, ~-I- /-1--1-1-.1_/- I 1.1. 1.1. ! I \. --' ¡ ¡ I i .-.-:-;-,----..... .'[2 §g ,0 ;0 ,0 :(~ 0 !--' 1--, '-J! I ' f·-. 6 ~97A C~' L ¡Z ¡Z ¡Z :z 1Z ,0' ,O! it':. I l"t . w LU:W IW ! .U , . ·I-u :ð:« ¡¿ ! U U~I'P MIl rr.fI '''''' !P< .,v5 'c¡ii ," -:.sL.. E"r~Jt'1st ct M' Çj .;U4 '!: .,. '1\':~ ", õ! .~ ';«/ ....! .. - r. . I ! - DiViSfUN. t.;;.'r..OiL A.1i~i.!) f..Þ5-,,· \ L.rl~f~f-l·u~I'~ i\ 'Y~~~WGFAtASk~ ..',. . u. . ~ OIL AND GAS CONSERVATION COMMITTEE" 11100.1-SB12 Ser: 106 PERMIT TO DRILL OR DEEPEN 8. LEASE DmlGNATION AND SERIAL NO. Naval Petroleum Reserve #4 la. TYPII or woaK DRILL GI DEEPEN fKJ 7. IF INDI."N, AU.O'ITEE OR TRIBE NAME N/A b. TYPII or WIILL OIL 0 0&11 ~ WIILL WIILL ~ 2. NAME OF OPERATOR oTBlla IIINGLII ZONII 00 MtlJ.TlrL& 0 ZONE 8. UNIT FARM OR LEASE NAME Director, Naval Petroleum & Oil Shale Reserves 3. ADDRESS r::JF OPERATOR N/A 9. WELL NO. 12 Rm. 550, Crystal Plaza #6, Washington, DC 20360* ~. LOCATION OF WELL At surface Alãska State Coord. System Zone 6: 6,305,300N; 695,850E; Umiat At proposed prod. zone Prime Meridian Same as surface 13. DISTANCE IN MILES AND DIRECTION FKOM NEAREST TOWN OR POST OFFICE' 10. FIELD AND POOL, OR WILDCAT Wildcat 11. SEC.. T.. R.. M.. (BOTTOM HOLE OBJECTIVE) Sect 26. T22N, R17W 12. 10.6 mi 14. BOND INFORMATION: TYPE N/ A N/A N/A . Amount 17. NO. ACRES ASSIGNED TO THiS WELL N/A Surety and/or No. IS. DISTANCE FROM PROPOSED· LOCATION TO NEAREST PROPERTY OR LEASE LINE, FT. (Also to nearest drig, unit, if any) 18. DISTANCE FROM PROPOSED LOCATION' TO NEAREST WELL DRILLING. COMPLETED. OR APPLIED FOR. FT. 18. NO. OF ACRES IN LEASE· 19. PROPOSED DEPTH 20. ROTARY OR CABLE TOOLS 5,9 mi 21. ELEVATIONS (Show whethcr DF, RT, CR. etc.> 2,350 ft Rotary 22. APPROX. DATE WORK WILL START' Ground: Approx, 12 ft MSL; KB ~ 16 ft MSL 23. PROPOSED CASING AND CEMENTING PROGRAM 09 MAR 74 SIZE OF HOLE SIZE OF CASING WEIGHT PER FOOT GRADE .... 14 3/4 ir.. 10 3/4 iL 51 lb ~-80 9 5/8 in 7 in 23 lb J-55 Open hole from apµrQx 1.650 to 1 750 ft SETI'ING DEPTH quantity af ~ement 1,260 ft 750 sx (theoretical) 1,650 ft 436 sx (theoretical) with 5-in per=. liner. The Director, Naval Petroleum and Oil Shale Reserves intends to drill a well in Sect. 26, T22N, R17W, Umiat PM. The Contractor is Pacific Architects and Engineers, Inc., Los Angeles, Calif. The well is being drilled to test the South Barrow Gas Sand in a structure about 6 mi from. the presently ¥roducing structure. It will be drilled through the South Barrow Gas Sand to test deeper horizons for possible productivity. If gas is found in the South Barrow Gas Sand, but no deeper pay is found, deeper zones will be isolated by cement plugs and the well completed as shown above. If deeper production is found, a revised program will be submitted, The well is being drilled to augment the reserves of gas available to meet the needs of government facilities in the area, and the community of Barrow. (cont. on reverse side' IN ABOVk SÞ'ACE DESCRIBE PROPOSED PROGRAM: If propooal Is to deepen give data on þresent productive tone ~d proposed new prôductive zone. Jf_ A:ro""pº-sal 111. ~ _ ar1l1_ or deepen cl1re~i.onauy. Itve pe.ru.nent datA" on subsurface )Qcàtions and mea$ured. and vue ·vertlcal depths. Give blowout prevettt"r program. 24. I hereby STGNrD F.a~C. USN DATE 24 FEB 74 ~Officer in Charge (This space for State office use) SAMPLES AND CORE CHIPS R.EQVUIIID o YES 0 NO DIRECTIONAL SURVEY REC/vtlU!:D CONDITIONS I MUD LO'C DYES ···0 NO OF APPROVAL, IF ANY: CYnŒR REQUIREMENTS: A.P.I. NVMDUCAL CODE DYES o NO So -02.:3 .- 2.000 G:. PERMIT NO APPROVAL DATIl: APPROVED BY TlTLII. -See Instructions On R....... Side PAD . . ......._ "'Ut ....."uX'tf.:-þ ..... ftW ,. .......... ,...m-r-....... _iQ... nl~. -..I i-.S:Þl-__ Oü ..... '.nllt... a.... ....... ..., 1'..,1" ..... ..... ..............1 .,................. ':uo), .~'r4A.:". 4. ....... "mt;~ "7'S.. INSTRUCTIONS General: A filing fee of $100.00 must accompany application for permit to drill or deepen. Checks shall he made out to State of 'Alaska ~epartmento£Revenue. This form is designed for submittinp, proposals to perform certain well operations. as indicated, on all types of lands and leases for appropriate action by the State agency, pursuant to applicable State laws and regulations. Any necessary special instructions concerning the use of· ,this form either are shown belów or may be obtained from the Division of Oil and Gas. Item 1: Use this form, with appropriate notations, if the proposal is to redrill to the same reservoir at a different subsurface location or redrill to a new reservoir. Item 13: Attach hereto a neat, accurate plat or map, drawn to scale, showing the site or proposed site for this location, distances from section line, iease line ,if any, and other information that is pertinent. Refer to Section 51.050 of Oil and Gas Regulations. Item 14: Enclose drilling bond on Form 10-402 with this application for permit to drill, or deepen, unless covered by other suitable bond.. , Item 15 and 18: If well is to be, or has been directionally drilled, use subsurface location of hole in any present or objective productive zone. i IV . . 4 NO. NAVAL PETROLEUM RESERVE SOUTH BARRO\¡V FIELD BARROW, ALASKA WELL 12 LOCATION I: 63,360 "4(;'0 0.0/ êl..SOIV t"i o (J :Þ' 1-3 H o Z ~oon /~ /8 E 5 8 6 7 /7 /8 . 22 2/ 20 ~ /9 /3 24 /4 South Barrow Well No 12 22.8' N of S line 1754.9'Wof Eline Sect. 23---0 22 II Výe /6 Test 2/ o Avak 20 /9 ~ -- 27 28 29 30 27 28 29 30 3/ 25 36 26 35 34 33 32 3/ 33 32 ~~ ~~ ~~ 3 4 5 T22N T2/N 6 t / 2 Lag A 3 4 5 6 ¿ . .J VJE L.. L ~¡:. '.. E ----;- .-.--. . . Depths,' KB (feet) \\\~\ ~ ;.¡: :¡.: ¡:'. !~ ( -::::--0.." I..; ~. '. .. 20 22" ho 1 e___ 160 170 1 4 %" ho I e 1067 1010 9 %" ho I e 1861 1869 1884 2053 2062 2088 2190 2255 7 % il core ho I e 2287 ~ ": .: ¡; . . . ~.. ~\.::: ~::: ~. " i Jj[ .~ ... ... .. .:.i.:: i{i; :;, .:i ... .~ COl'ilPLET .... ....:, :'. .,~: : :.:::, ~~i '0.: :'. ::~ .. .~.\ w ~ . ., :ž:·:.f. :: ':0':', " ''-- . . IO.PIZ (j .L I L E -- 24" Conductor, I jt. 16" 00 Casing, 4 jts, N-80, 75#If.t Range 3 8-Rnd T & C , 10%" 00 Casing, 29 Jts, P-51, 5111/ ft Range 3, Buttress T & C 2%" EUE Tubing, 65 jts, J-55, 6.5H/ft Range 2, 8 Rnd, T & C . >rJ..L. ".:.~:;;:::' .::::.~~ :;:::~ ..~ .~:.~ 0'::;-- .. '.. "r.: ~ ..., ~ ~}'~~ i·~·~~·;·Y·:::· .. Æ··..········::.. T!m:r. wJ -::: ;::::: ~ ' Liner ""'t--- Brown í.~ B I an k J-55, (no scale) 7" Extreme Line Casing, 48 jts, Extreme Line, 23ßlft, Range 3, flush joint l'Janger S lips Liner Hanger 51/2" Liner, Secu....it" 20#/ft. Range 3 Flush .Joint, Slotted 5%" Liner, Security Flush Joint J-55, 20Hlft, Range 3 Cement Plug WELL 12 PROFILE South Barrow Field Naval Petroleum Reserve No. 1 Alaska EXPLANATION . OIL WELL -¢- GAS WELL . OIL AND GAS WELL 4- OIL SHOW-ABANDONED ~ GAS SHOW-ABANDONED .. SUSPENDED GAS WELL . ~ OIL AND GAS SHOW ABANDONED -<:>- DRY AND ABANDONED . SUSPENDED OIL WELL . -- ---- .-----------.---. -..--- -- .--.-.---"..-.. . --~----_._._-.'-~- .:.. , - , .~. , ,- I .". ,.. B~RROW ARE~:~ 0 c . . ' ·Cc,. TULAGEAK 1 ê -'1 4- S.BARRO ;"Q~;'1]~D SE 1 ~A~~~~~P2A~ :~ B~Y~ l .. SIMPSON 1 . CA. . . . , +. - IlUy' ~ "'~" t,:E. SIMPSON 2 ULL CL~FF.!X· I' - .Ä~..r..i' .. E. SI~PSQt1Ll_~. J. W. DALTON I ~.. 'm. .:~ ¥' . ~ .j'~~; SIMPSON 1_ ..... ~.: W. T. FO~AN I ~ ,t>-pEARD I ~I -'-. j , <' ,('-v.:rJ ::.K DREW. .~-.- . ( :., ,'- '. - /, ~ ï: \;J,~.. POINT f /CAPE HALKETT I , , -+ ~m'-r'-' . :rÇlfAG6RUK ~. . ~ S ~PspN '.:..... fÍ ",. . . ", .,..."..... .~- ~ ,-,'.r,: . K.UGR,. U,fJ. I. r)~.:;lr , ' ' E. T. Op.~, RÚK f:l:;TESHEPUK µ,.. ~~' _ ., ATfGARU :, . ¡, . i .r· y- I . -. ~ "- . -.- '~\m.""" ..··T ~ -:. ., POINT I : ¡ .--"~:__._)":\, S.MEADE I. . . . Y.' _.IKPUK..l ,.,=""..,.. "-'. J, j~:4è-.:..-L. u.. J. 1¡.~t:., ' :. J.t'... ,.~ J.~ 4- ',\\è-.N.KALlKPIKJ' . /~,~H::RISON: ./Í - . .--'--. L.', ' ~ ~" ',. W. FISH CREEK '!¿f..:;l"'-~Y~ ¡ /'/ , ~_T,UNA,L.IK 1 , .__~ ~_ ~.: ' ~. ~. ~ ~ ~:I!ÍliG6K 1·4 ../' ,~~I~H') U / -_ 'Yi-~ ì u. . . + ... \). ~ .~L, ...... ? ,..,~!ít' CREEK IV ! , ~': +fl-)~"'~-:- ',,~._~¿.,,~_...:~- ~... "'li:;.~'- ;~1~ ,. . ..~ .&JJ;, ...... ;~ j..~~~ ! .... ---~'1<A'OLAK I ,_,'_.__ ._. _ '_. ! _ . ~,T.......... ___. "S*-,.NI~OK·I + - rfKIWK"'f t, .. ___. 'd"'_ :.. " + . . ",. . . ___ T ,.. '7 + y ,I\IVER I ~,..__ '¡ _...' ' (." t ) r'-~, '-, "1..- _.___~..__ - ---....-- ~ . . OUMALlK I :;". . . . ,"('US ry ,. í: .. ~,~, .~. ' --.. . ----.. ,....;1 *-*.OUMALliu ' . .'" ..!~ I"-<_~. j ~,l.LI - l 'r' r'· . ; -.-. .. r ... .L.T . '. :\,I...Ko.µJKTIlK I. ! ¡' t L" I ' ""-,,____...... ...JL_..! ..1.._-"- J !.. ~ -.....;;. __.' '" ,.SENTlNEL ,.-..-__... _~.~~--- '., .'. : "·1·"·" -." ! '~'IHILLI 1-.--- . ' ( -¡-- - . .. . . " f , . ~Q\JAijE, . i I, C"- -! - -1,-+--- . ---~.~~ . . " -' yLAKE"I F1i"BIK L,,' ~ "',' :..,' \...:- .' _ --.. _ L,; -[;j TITALUK ~. : WOLF~ SEABEE I.' I I ' I . ' \ th.. ... ".. CREEK \ 4- . .' ~ ""_.).. .", 1 23 ~.. UMIAT t .:. __ ..-'y L . ~ tÀ . A.... ,'- t. . . . - ,- :1'" AREA -(, ~ ./. -oJ· . I ".- GUBIK /--. T '.~: . ]~--~. .." . ~ t· . ---/. 2 . -_t-"L...'L'-l'.f:~ ' -~ . - 1-4WUNA I, ;::!. . -<;P-r'KNIFEBLADE~ f· : ·ri . . -t' .J.-~,:",o-''--,-'':~ i .~ ..y.__,""'..I.~ ~ i --'. . ~ .. ' - ". . . ... . . . ;....--., "- ~ .. :F W r -. . '5' ,.' __' -. -- . . . . . .; ,-- ""~~ ",'" GRANDSTAND I r' ,./....~.-..:..:.:...-:...~·I .4:.. ~........,--. ;' . , , . , '-+- . /'../,__'T---·~~~ . ",,' ,.:: ~ ~ .: . .1 - ...."............ ...,.- " . .. ,. , ............ ,. .. '- .. . . ··~LlSBURNE I v~~k ~6..é ,"ì1 5,0 Mi. I ;~~ _f\~~ ... I 75 Km. ~O:O O~O ......_~ ! ø ! "'\-' I <.. .' \J ---+- ---- ---~--------...---_..- ---- ---..-- I-~ C TIC Þ. It + + t · . C' H U I' , .. I ~~ T~~~~~~c..._ o ! 25 I INOEX MAP-PET-48 NPRA TEST WELLS AND SELECTED CORE TESTS, 1944 - 53. 1914 - 81 ALUKA HPR ò 2'5 50 - , ""0· _·__··J.W.8RUYH'~L r=t;.:;- j ~"'E.C",-~ ...., "1- ·~··..u, __ . ~_._-._--- __u . _ ___.'__. ____ ._. _ ---.-...-- - TETRA TECH REPORT NO.8200 I~ -¢- + "* ..- ~ ~ ~ ~ ~ ~ ~ -V- *" ~ ~ -¢- -$- ~ ~ .; I- i+ + ø . . If -V- . ø If -V- BARROW AREA' ARCON BARROW I S. BARROW I S. BARROW 2 S. BARROW 4 S. BARROW 5 S. BARROW 6 S. BARROW 7 S.. BARROW 8 s. BARROW 9 S. BARROW 10 S. BARROW II . S. BARROW 12 S. BARROW 13 S. BARROW 14 s. BARROW 15 S. BARROW 16 S. BARROW 17 S. BARROW 18 S. BARROW £9 S.BARROW 20 AVAK I UMIAT AREA I UMIAT I UMIAT 2 UMIAT 3 UMiAT 4 UMIAT 5 UMIAT 6 UMIAT 7 UMIAT 8 UMIAT 9 UMIAT 10 UMIAT II FI~' IIRF' ? \Q ~ ) 8 ---' t' !,~.~:....:.... '''' '.._:",~ . "Old" ., .,a"\")' \';ells (1944-S3) Well Name ì t j Avak -, IOO-Oé}~ South Barrow-l /00 -08""3 South Barrow-2 I ()D -DB'! South . Barrow-3 laD ';"'6~ I South Barrow-4 IOO~O~' Fish Creek-liDO -)ðÒ j GJiandstand-l 100 -(þ5'""3 , Gubik-l {bð-:;).9./ ¡ I Gubik-2 I DO -:):J;;) . Kaolak-l 100 -[)Q4f Knifeblade-l JðO - II) I Y.nifeblade-2 I OD -I;;.{) Knifeblade-2A ì:s r\OC4J J<'...iPe.JøkWe 6- l1eaàe-l Ou.'tIalik-l IDO-f/"I Eas.t OU1'nalik-1 10D -116- Simpson-1 I [)() -I '" ~ Nðrf , S,'",p:;ÞI1-1 }ðO-DI1/'" Squ'are Lake-1 J 00 _I/(, Tita.luk-1 IOb-IQÖ Topagoruk-1 JoO -tG}S- Ea~t Topagoruk -1 I a"J -to, t) Umiat-l IDC -QeD, Umiat-2 100 -~'D Umiat-3 (oo-().{ I Umiat-4 IDO ,é}/~ Umiat-5 /00 -:;H3 Umiat-6 100 -d/~l¡ Urniat-7 IOÓ -a/cl I Umiat-B IOP-;)l(,¡, j Umiat-9 JðO -QI1- J Umiat-10 IDD-f.)l1f Umiat-1.1 lDO ...é)/~ Wolf Creek-1 1bD-11~ r Wolf Creek-2 Juo-Ú t'ö j Wolf Creek-3 /(b-J I") .,..___ _... e·__" ..,._.' _no ___. ..~..,:._._... ..._.~ _ ..._~, __..._......_. ..-_ ~ , I 1 i': I , . : 1 f , t J . i ) , , "Intermediate" Wells at Barrow. (1955-1974) South Barrow-5 It>ó-b~15 ,South Barrow-6 i (5() - öclo., ., South Barrow-7 16b·-O'3D South Barrow-8 /06!-031 South Barrow-9 Ibö-ã3;¿ South Barrow-10 1d.>-ó33 South Barrow-l1 It:$> -ó'3J.( ~ South Barrow-12 lðD-ò~ .; .._.__.,·,____··__n..·_n.__. .. '_-'_.,,---,,~.'-"- ~~
