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Home My WebLink AboutAEO 002AQUIFER EXEMPTION ORDER #2 Milne Point 1. May 1, 1987 2. May 8, 1987 3. May 15, 1987 4. May 27, 1987 5. June 12, 1987 6. June 18, 1987 7. July 2, 1987 8. February 1, 1988 9. September 27, 2004 Conoco Application for AEO Milne Point Ltr from AOGCC to US EPA re: application Notice of Hearing and Affidavit of Publication US EPA ltr re: Questions Conoco's Supplement application AOGCC ltr to US EPA re: Questions US EPA concurrence of approving application Conoco's request for Administrative Approval AOGCC's proposal to amend underground injection orders to incorporate consistent language addressing the mechanical integrity of wells AQUIFER EXEMPTION ORDER #2 . . STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION 3001 Porcupine Drive Anchorage, Alaska 99501-3912 Re: THE REQUEST OF CONOCO, ) INC. for an aquifer ) exemption order for the ) Milne Point Unit. ) Aquifer Exemption Order No. 2 Milne Point Unit Kuparuk River Field July 8, 1987 IT APPEARING THAT: 1. Conoco, Inc. (Conoco), by letter of May 1, 1987, requested that the Alaska Oil and Gas Conservation Commission issue an order exempting those portions of all freshwater aquifers lying directly below the Milne Point Unit for Class II injection activities. 2. Notice of an opportunity for a public hearing on June 11, 1987 was published in the Anchorage Daily News on May 15, 1987. 3. Neither a protest nor a request for a public hearing was timely filed. Accordingly, the Commission will, in its discretion, issue an order without a public hearing. 4. A copy of Conoco's request was forwarded to the U.S. Environmental Protection Agency (EPA)-Region 10 on May 8, 1987 in conformance with Section 13 of the Memorandum of Agreement, between the Alaska Oil and Gas Conservation Commission and EPA, effective June 19, 1986. 5. A request for additional information was received from EPA on June 1, 1987, and a copy of Conoco's "Supplement to the Application..." dated June 12, 1987 was forwarded to EPA on June 18, 1987. Aquifer ExemPti~ Order July 8, 1987 Page 2 No. 2 . FINDINGS: 1. Those portions of freshwater aquifers occurring beneath the Milne Point Unit do not currently serve as a source of drinking water. 2. Those portions of freshwater aquifers occurring beneath the Milne Point Unit are situated at a depth and location that makes recovery of water for drinking water purposes economically impracticable. 3. Those portions of freshwater aquifers occurring beneath the Milne Point Unit are reported to have a total dissolved solids content of more than 3000 and less than 10,000 mg/l, and are not reasonably expected to supply a public water system. 4. By letter of July 2, 1987, EPA-Region 10 advises that the aquifers occurring beneath the Milne Point Unit qualify for exemption. It is considered to be a minor exemption and a non-substantial program revision not requiring notice in the Federal Register. 5. The Milne Point Unit area constitutes a compact land parcel which can readily be described by governmental subdivisions. CONCLUSION: Those portions of freshwater aquifers lying directly below Milne Point Unit qualify as exempt freshwater aquifers under 20 AAC 25.440. NOW, THEREFORE, IT IS ORDERED THAT the portions of aquifers on the North Slope described by the one-quarter (%) mile area beyond and lying directly below the following tracts of land are exempted for Class II injection activities only. Umiat Meridian T13N R9E T13N R10E T13N RIlE Sections 13, 14, 23 and 24. All Sections. Sections 5, 6, 7, 8, 15, 16, 17, 18, 19, 20, 21, 22, 29, 30, 31 and 32. Aquifer Exemptio Order No. 2 July 8, 1987 Page 3 DONE at Anchorage, Alaska, and dated July 8, 1987. A 01 TjON cow J Alaska Uil and Gas Conservation Commission Lob -hie C. Smith, Commissioner Alaska Oil and Gas Conservation Commission W. W. Barnwell, Commissioner Alaska Oil and Gas Conservation Commission #9 LJ FRANK H. MURKOWSKI, GOVERNOR �t ALASKA OIL AND GALS �r 333 W. T" AVENUE, SUITE 100 CONSERVATION COMII55IDN j' ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 September 27, 2004 Proposals to Amend Underground Injection Orders to Incorporate Consistent Language Addressing the Mechanical Integrity of Wells The Alaska Oil and Gas Conservation Commission ("Commission"), on its own motion, proposes to amend the rules addressing mechanical integrity of wells in all existing area injection orders, storage injection orders, enhanced recovery injection orders, and disposal injection orders. There are numerous different versions of wording used for each of the rules that create confusion and inconsistent implementation of well integrity requirements for injection wells when pressure communication or leakage is indicated. In several injection orders, there are no rules addressing requirements for notification and well disposition when a well integrity failure is identified. Wording used for the administrative approval rule in injection orders is similarly inconsistent. The Commission proposes these three rules as replacements in all injection orders: Demonstration of Mechanical IntegritX The mechanical integrity of an injection well must be demonstrated before injection begins, at least once every four years thereafter (except at least once every two years in the case of a slurry injection well), and before returning a well to service following a workover affecting mechanical integrity. Unless an alternate means is approved by the Commission, mechanical integrity must be demonstrated by a tubing/casing annulus pressure test using a surface pressure of 1500 psi or 0.25 psi/ft multiplied by the vertical depth of the packer, whichever is greater, that shows stabilizing pressure and does not change more than 10 percent during a 30 minute period. The Commission must be notified at least 24 hours in advance to enable a representative to witness mechanical integrity tests. Well Integrity Failure and Confinement Whenever any pressure communication, leakage or lack of injection zone isolation is indicated by injection rate, operating pressure observation, test, survey, log, or other evidence, the operator shall immediately notify the Commission and submit a plan of corrective action on a Form 10-403 for Commission approval. The operator shall immediately shut in the well if continued operation would be unsafe or would threaten contamination of freshwater, or if so directed by the Commission. A monthly report of daily tubing and casing annuli pressures and injection rates must be provided to the Commission for all injection wells indicating well integrity failure or lack of injection zone isolation. Administrative Actions Unless notice and public hearing is otherwise required, the Commission may administratively waive or amend any rule stated above as long as the change does not promote waste or jeopardize correlative rights, is based on sound engineering and geoscience principles, and will not result in fluid movement outside of the authorized injection zone. The following table identifies the specific rules affected by the rewrite. Injection Order "Demonstration of Mechanical Integrity" A ffected Rules "Well Integrity Failure and Confinement" " Administrative Action" Area In,i ection Orders AlO 1 - Duck Island Unit AIO 2B - Kuparuk River Unit; Kuparuk River, Tabasco, U gnu, West Sak Fields AIO 3 - Prudhoe Bay Unit; Western Operating Area AIO 4C - Prudhoe Bay Unit; Eastern Operating Area AIO 5 - Trading Bay Unit; McArthur River Field AIO 6 - Granite Point Field; Northern Portion AIO 7 - ,Middle Ground Shoal; Northern Portion AlO 8 - Middle Ground Shoal; Southern Portion AIO 9 - Middle Ground Shoal; Central Portion AIO 1 DB - Milne Point Unit; Schrader Bluff, Sag River, Kuparuk River Pools AIO 11 - Granite Point Field; Southern Portion AIO 12 - Trading Bay Field; Southern Portion AIO 13A - Swanson River Unit AIO I4A - Prudhoe Bay Unit; Niakuk Oil Pool AIO 15 - West McArthur 6 7 9 6 7 9 6 7 9 6 7 9 6 6 9 6 7 9 6 7 9 6 7 9 6 7 9 4 5 8 5 6 8 5 6 8 6 7 9 4 5 8 5 6 9 ) ) Affected Rules "Demonstration of "Well Integrity "Administrative Injection Order Mechanical Failure and Action" Integrity" Confinement" River Unit AIO 16 - Kuparuk River 6 7 10 Unit; Tam Oil Pool 6 8 AIO 1 7 - Badami Unit 5 AIO 18A - Colville River 6 7 11 Unit; Alpine Oil Pool AIO 19 - Duck Island Unit; 5 6 9 Eider Oil Pool AIO 20 - Prudhoe Bay Unit; 5 6 9 Midnight Sun Oil Pool AIO 21 - Kuparuk River 4 No rule 6 Unit; Meltwater Oil Pool AIO 22C - Prudhoe Bay 5 No rule 8 Unit' Aurora Oil Pool 9 , 6 AIO 23 - Northstar Unit 5 AIO 24 - Prudhoe Bay Unit; 5 No rule 9 Borealis Oil Poo I AIO 25 - Prudhoe Bay Unit; 6 8 13 Polaris Oil Pool AIO 26 - Prudhoe Bay Unit; 6 No rule 13 Orion Oil Pool Disposal Injection Orders DIO 1 - Kenai Unit; KU No rule No rule No rule WD-1 DIO 2 - Kenai Unit; KU 14- No rule No rule No rule 4 DIG 3 - Beluga River Gas No rule No rule No rule Field; BR WD-l DIO 4 - Beaver Creek Unit; No rule No rule No rule BC-2 DIG 5 - Barrow Gas Field; No rule No rule No rule South Barrow #5 DIO 6 - Lewis River Gas No rule No rule 3 Field; WD-l DIG 7 - West McArthur 2 3 5 River Unit; WMRU D-1 DIG 8 - Beaver Creek Unit; 2 3 5 BC-3 DIG 9 - Kenai Unit; KU 11- 2 3 4 17 DIO 10- Granite Point 2 3 5 Field; GP 44-11 Affected Rules "Demonstration of "Well Integrity "Administrati ve Injection Order Mechanical Failure and Action" Integrity" Confinement" DIO 11 - Kenai Unit; KU 2 3 4 24-7 010 12 - Badami Unit; WD- 2 3 5 1, WD- 2 010 13 - North Trading Bay 2 3 6 Unit; S-4 010 14 - Houston Gas 2 3 5 Field; Well #3 DIO 15 - North Trading Bay 2 3 Rule not numbered Unit; S-5 010 16- West McArthur 2 3 5 River Unit; WMRU 4D DIO 17 - North Cook Inlet 2 3 6 Unit; NCfUA-12 DIO 19 - Granite Point 6 Field; W. Granite Point State 3 4 17587 #3 DIO 20 - Pioneer Unit; Well 3 4 6 1702-150A WDW 01021 - Flaxman Island; 3 4 7 Alaska State A-2 DIO 22 - Redoubt Unit; RU 3 No rule 6 Dl DIO 23 - Ivan River Unit; No rule No rule 6 IRU 14-31 010 24 - Nicolai Creek Order exp ired Unit; NCU #5 DIO 25 - Sterling Unit; SU 3 4 7 43-9 010 26 - Kustatan Field; 3 4 7 KFl Storage Injection Orders SIO 1 - Prudhoe Bay Unit, No rule No rule No rule Point McIntyre Field #6 S10 2A- Swanson River 2 No rule 6 Unit;KGSF #1 SIO 3 - Swanson River Unit; 2 No rule 7 KGSF #2 Enhanced Recovery Injection Orders ErO 1 - Prudhoe Bay Unit; No rule 8 Prudhoe Bay Field, Schrader No rule Bluff Formation Well V-I05 Inj ection Order EIO 2 - Redoubt Unit; RU-6 ) "Demonstration 0 f Mechanical Integrity" 5 " ') Affected Rules "Well Integrity Failure and Confinement" 8 "Administrative Action" 9 02-902 (Rev. 3/94) Publisher/Original Copies: Department Fiscal, Department, Receiving AO.FRM STATE OF ALASKA ADVERTISING ORDER §eJ;;.B()TT()M··F()~·I~VOI~EAI!)ÐRf:SS NOTICE TO PUBLISHER ADVERTISING ORDER NO. INVOICE MUST BE IN TRIPLICATE SHOWING ADVERTISING ORDER NO., CERTIFIED AO-02514016 AFFIDAVIT OF PUBLICATION (PART 2 OF THIS FORM) WITH ATTACHED COpy OF ADVERTISEMENT MUST BE SUBMITTED WITH INVOICE F AOGCC 333 West th Avenue, Suite 100 Åû1chorage,AJC 99501 907-793-1221 i\GENCY CONTACT DATE OF A.O. R o M lady Colomhie September 77, ?004 PHONE PC\¡ _(907) 793 -] ?7] DA TES ADVERTISEMENT REQVIRED: T o Journal of Commerce 301 Arctic Slope Ave #350 Anchorage, AK 99518 October 3, 2004 THE MATERIAL BETWEEN THE DOUBLE LINES Mt:ST BE PRINTED IN ITS ENTIRETY ON THE DATES SHOWN. SPECIAL INSTRUCTIONS: United states of America AFFIDAVIT OF PUBLICATION REMINDER State of ss INVOICE MUST BE IN TRIPLICATE AND MUST REFERENCE THE ADVERTISING ORDER NUMBER. A CERTIFIED COPY OF THIS AFFIDAVIT OF PUBLICATION MUST BE SUBMllTED WITH THE INVOICE. ATTACH PROOF OF PUBLICATION HERE. division. Before me, the undersigned, a notary public this day personally appeared who, being first duly sworn, according to law, says that he/she is the of Published at in said division and state of and that the advertisement, of which the annexed is a true copy, was published in said publication on the day of 2004, and thereafter for _ consecutive days, the last publication appearing on the _ day of . 2004, and that the rate charged thereon is not in excess of the rate charged private individuals. Subscribed and sworn to before me This _ day of 2004, Notary public for state of My commission expires Public Notices I of 2 9/29/2004 1: 10 PM Public Notices J(le~se find th~ attached Notice and Attachment for the proposed amendment of underground injection orders and the Public Notice Happy Valley #10. Jody Colombie , Content-Type: application/rnsword : Mechanical IntegrityproposaI.doc·¡ . .. ... .. .... . b·· .. 6·4·...·..· . ¡Content-EncQ(lJ.pg: ·ase . '~k'"'' ._.... ',.. .",......_"R_._. ___, '. . ... __... ......,... _,,_._.. ._",~... .... .... . . ... .... .... ... ... . .. .... ... .1 COlltèut-Type: applicatíonJrnsword Mechanical Integrity of Wells N otice.doc!·. .. ... .. . .. - .. . ..þ 6· .4 ! Content-Encoding: ··ase I Content-Type: application/msword BappyValley1. 0_ HearingNotice.doc Content-Encodllig:base64 ". . ~.-. ~'. '".'.,...- . .,. ". ... ".. ..-."., .".. ..,.. '_""'.._," .,.,.,.__....,,_ _' ,. .',. _,.. .~,,,,,'._..""__'.,~._._.... '~__'_"__" ·.._.·,,···..·_,·····__··'_'""T.·'··_, 20f2 9/29/2004 1: 10 PM Public Notice " Subject: Public Notice From: J ody Colombie <jody _ colombie@admin.state;ak.us> Date: 29 2004 12:55:26 -0800 Please publish the attached Notice on October 3, 2004. Thank you. Jody Colombie Mechanical Integrity of Wells Content- Type: applicationlmsword Content-Encoding: base64 Content-Type: applicationlmsword . Ad Order form.doc Content-Encoding: base64 l of 1 9/29/2004 1: 10 PM Citgo Petroleum Corporation PO Box 3758 Tulsa. OK 74136 Mary Jones XTO Energy, Inc. Cartography 810 Houston Street, Ste 2000 Ft. Worth. TX 76102-6298 /'1al/~d l{Íf/ð'~ i David McCaleb IHS Energy Group GEPS 5333 Westheimer, Ste 100 Houston. TX 77056 Kelly Valadez Tesoro Refining and Marketing Co. Supply & Distribution 300 Concord Plaza Drive San Antonio, TX 78216 Robert Gravely 7681 South Kit Carson Drive Littleton, CO 80122 George Vaught, Jr. PO Box 13557 Denver, CO 80201-3557 Jerry Hodgden Hodgden Oil Com pany 408 18th Street Golden, CO 80401-2433 Richard Neahring NRG Associates President PO Box 1655 Colorado Springs, CO 80901 John Levorsen 200 North 3rd Street. #1202 Boise,ID 83702 Kay Munger Munger Oil Information Service. Inc PO Box 45738 Los Angeles, CA 90045-0738 Samuel Van Vactor Economic Insight Inc. 3004 SW First Ave. Portland. OR 97201 Michael Parks Marple's Business Newsletter 117 West Mercer St, Ste 200 Seattle, WA 98119-3960 Mark Wedman Halliburton 6900 Arctic Blvd. Anchorage. AK 99502 Schlumberger Drilling and Measurements 2525 Gambell Street #400 Anchorage. AK 99503 David Cusato 200 West 34th PMB 411 Anchorage, AK 99503 Baker Oil Tools 4730 Business Park Blvd., #44 Anchorage. AK 99503 Ciri Land Department PO Box 93330 Anchorage, AK 99503 Jill Schneider US Geological Survey 4200 University Dr. Anchorage, AK 99508 Gordon Severson 3201 Westmar Cr. Anchorage. AK 99508-4336 Jack Hakkila PO Box 190083 Anchorage. AK 99519 Darwin Waldsmith PO Box 39309 Ninilchick, AK 99639 James Gibbs PO Box 1597 Soldotna. AK 99669 Kenai National Wildlife Refuge Refuge Manager PO Box 2139 Soldotna. AK 99669-2139 Penny Vadla 399 West Riverview Avenue Soldotna. AK 99669-7714 Richard Wagner PO Box 60868 Fairbanks, AK 99706 Cliff Burglin PO Box 70131 Fairbanks, AK 99707 Bernie Karl K&K Recycling Inc. PO Box 58055 Fairbanks. AK 99711 Williams Thomas Arctic Slope Regional Corporation Land Department PO Box 129 Barrow, AK 99723 North Slope Borough PO Box 69 Barrow, AK 99723 .[Fwd: Re: Consistent Wording for Injection ( )s - Well Integrity... ) ~ubject:. [Fwd: Re: ·Consistent WorØirr~for~j~cti()nOrders ~.·Wellmt¢gri~)l(R.eviseg)l F~o~: John Norman<jo~norman@a(jmin~state.ak.u~> Date: Fri, 01· Oct 200411:09:26<~0800 '1'6;:... ··JOClý·.j···Ç6tQtÍ1þJè··..~.ö4y_ 6~)IÒ~bi~@(ldinj~·~tªfé..åk.µs?·· more -------- Original Message -------- Subject:Re: Consistent Wording for Injection Orders - Well Integrity (Revised) Date: Wed, 25 Aug 2004 16:49:40 -0800 From:Rob Mintz <robert lTIintz@law.state.ak.us> To:iim regg@admin.state.ak.us CC:dan seamount@admin.state.ak.us, john norman@admin.state.ak.us Jim, looks good, but I still think maybe it would be good to include the following sentence or something like it in the well integrity and confinement rule: "The operator shall shut in the well if so directed by the Commission." My thinking is that otherwise, an operator might argue that the Commission can only require the well to be shut in by going through an enforcement action, issuing an order after notice and opportunity for hearing, or meeting the strict requirements for an emergency order under the regulations. The proposed language makes clear that it is a condition of the authorization to inject, that the operator must shut in the well if directed by the Commission after a notification of loss of integrity, etc. »> James Regg <¡im regg@admin.state.ak.us> 8/25/2004 3: 15:06 PM »> Rob - Thanks for the review; here's a redraft after considering your comments. I have accepted most of the suggested edits; also attached is response to questions you pose (responses are embedded in the comments, using brackets [JBR - ...] to set apart from your questions). Jim Regg Rob Mintz wrote: Jim, I have some questions about the draft language, which are shown as comments on the first document attached. Based on my current guesses about what the answers will be to my questions, I also have some suggested edits, which are shown as redlines on the second document attached. »> James Regg <¡im regg~admin.state.ak.us> 8/17/20044:33:52 PM »> Please delete previous version (email sent 8/9/04); I found another inconsistency in the injection orders regarding well integrity that I have integrated into the proposed fix. Attached is a proposal for consistent language in our injection orders addressing 3 rules related to well integrity: - "Demonstration of Tubing/Casing Annulus Mechanical Integrity" - "Well Integrity Failure" - If Administrative Actions". This proposal includes input from all Sr. staff (except Jack). If you agree with the approach, I'll work with Jody to prepare the public notice. Main points - Demonstration of Tubing/Casing Annulus Mechanical Integrity - standardizes the wording used for mechanical integrity demonstrations, and establishes abililty to grant alternate methods (e.g., temp survey, logging, pressure monitoring in lieu of pressure testing lof2 10/2/2004 4:07 PM [Fwd: Re: Consistent Wording tor Injectior iers - Well Integrity... - specific to AIO 2C for Kuparuk, there is wording that is more appropriately included in Well Integrity Failure (i.e., more frequent MITs when communication demonstrated) - establishes more frequent MIT schedule for slurry injection wells (every 2 yrs) which is consistent with our current practice (but not addressed in regulations) Well Integrity Failure - retitles to "Well Integrity Failure and Confinement"; inserted language regarding injection zone integrity (see DIO 25 and 26) - consistent language regardless of type of injection (disposal, EOR, storage); - eliminates requirement for immediate shut in and secure; allows continued injection until Commission requires shut in if there is no threat to freshwater; - eliminates delay in notifying Commission after detect leakage or communication ("i.e., "immediately notify"); - removes language about notifying "other state and federal" agencies; - requires submittal of corrective action plan via 10-403; - requires monthly report of daily injection rate and pressures (tubing and all casing annuli); this is a requirement we currently impose when notified of leak or pressure communication; - notice and action not restricted to leaks above casing shoe as stated in several DIOs Administrative Actions - adopts "Administrative Actions" title (earlier rules used "Administrative Relief"); - consistent language regardless of type of injection (disposal, EOR, storage); - uses "administratively waive or amend" in lieu of terms like "revise", "reissue", etc.; - adds geoscience to "sound engineering principles"; - language is more generic regarding fluid movement out of zone; existing versions mention varying combinations of protecting "freshwater", "aquifers", "USDWs"; "risk of fluid movement"; "fluid escape from disposal zone" Jim Regg John K. Norman <John Norman@admin.state.us> Commissioner Alaska Oil & Gas Conservation Commission 20f2 10/2/20044:07 PM JFwd: Re: Consistent Wording for Injection 0 , - Well Integrity... ) Subject: [Fwd: Re:ConsistentW ording for InjèctionOrders ~ Well Ihtègrity (J1evis~d)] ~rol1l: John Nonnan <john._norman@admin.stat~.ak.µs> Date: Fri, 01 Oct 2004 11:08:55 ··0800 please print all and put in file for me to review just prior to hearing on these amendments. thanx -------- Original Message -------- Subject:Re: Consistent Wording for Injection Orders - Well Integrity (Revised) Date:Thu, 19 Aug 2004 15:46:31 -0800 From:Rob Mintz <robert mintz@law.state.ak.us> To:dan seamount@admin.state.ak.us, jim regg@admin.state.ak.us, john nonnan@admin.state.ak.us Jim, I have some questions about the draft language, which are shown as comments on the first document attached. Based on my current guesses about what the answers will be to my questions, I also have some suggested edits, which are shown as red lines on the second document attached. »> James Regg <jim regg@Jadmin.state.ak.us> 8/17/20044:33:52 PM »> Please delete previous version (email sent 8/9/04); I found another inconsistency in the injection orders regarding well integrity that I have integrated into the proposed fix. Attached is a proposal for consistent language in our injection orders addressing 3 rules related to well integrity: - "Demonstration of Tubing/Casing Annulus Mechanical Integrity" - "Well Integrity Failure" - "Administrative Actions". This proposal includes input from all Sr. staff (except Jack). If you agree with the approach, I'll work with lody to prepare the public notice. Main points - Demonstration of Tubing/Casing Annulus Mechanical Integrity - standardizes the wording used for mechanical integrity demonstrations, and establishes abitilty to grant alternate methods (e.g., temp survey, logging, pressure monitoring in lieu of pressure testing - specific to AIO 2C for Kuparuk, there is wording that is more appropriately included in Well Integrity Failure (i.e., more frequent MITs when communication demonstrated) - establishes more frequent MIT schedule for slurry injection wells (every 2 yrs) which is consistent with our current practice (but not addressed in regulations) Well Integrity Failure - retitles to "Well Integrity Failure and Confinement"; inserted language regarding injection zone integrity (see DIG 25 and 26) - consistent language regardless of type of injection (disposal, EaR, storage); - eliminates requirement for immediate shut in and secure; allows continued injection until Commission requires shut in if there is no threat to freshwater; - eliminates delay in notifying Commission after detect leakage or communication ("i.e., "immediately notify"); - removes language about notifying "other state and federal" agencies; - requires submittal of corrective action plan via 10-403; - requires monthly report of daily injection rate and pressures (tubing and all casing annuli); this is a requirement we currently impose when notified of leak or pressure communication; - notice and action not restricted to leaks above casing shoe as stated in several DIOs Administrative Actions lof2 10/2/20044:07 PM [Fwd: Re: Consistent Wording for InjectiOl iers - Well Integrity... - adopts "Administrative Actions" title (earlier rules used "Administrative Relief'); - consistent language regardless of type of injection (disposal, EOR, storage); - uses "administratively waive or amend" in lieu of terms like "revise", "reissue", etc.; - adds geoscience to "sound engineering principles"; - language is more generic regarding fluid movement out of zone; existing versions mention varying combinations of protecting "freshwater", "aquifers", "USDWs"; "risk oftluid movement"; "fluid escape from disposal zone" Jim Regg : John K. Nonnan <John Norman@adrnin.state.us> Commissioner Alaska Oil & Gas Conservation Commission . Content-Type: applicationJrnsword Injection Order language - questions.doc Content-Encoding: base64 Content-Type: applicationJrnsword Injection Orders language edits.doc Content-Encoding: base64 20f2 10/2/2004 4:07 PM ) ) Standardized Language for Injection Orders Date: August 17, 2004 Author: Jim Regg Demonstration of Tubing/Casing Annulus Mechanical Integrity The mechanical integrity of an injection well must be demonstrated before injection begins, after a workover affecting mechanical integrity, and at least once every 4 years while actively injecting. For slurry injection wells, the tubing/casing annulus must be tested for mechanical integrity every 2 years. The MIT surface pressure must be 1500 psi or 0.25 psi/ft multiplied by the vertical depth, whichever is greater, must show stabilizing pressure and may not change more than 10% during a 30 minute period. Any alternate means of demonstrating mechanical integrity must be approved by the Commission. The Commission must be notified at least 24 hours in advance to enable a representative to witness pressure tests. Well Integrity Failure and Confinement The tubing, casing and packer of an injection well must demonstrate integrity during operation. The operator must immediately notify the Commission and submit a plan of corrective action on F onn 10-403 for Commission approval whenever any pressure communication, leakage or lack of injection zone isolation is indicated by injection rate, operating pressure observation, test, survey, or log. If there is no threat to freshwater, injection may continue until the Commission requires the well to be shut in or secured. A monthly report of daily tubing and casing annuli pressures and injection rates must be provided to the Commission for all injection wells indicating pressure communication or leakage. Administrative Actions Unless notice and public hearing is otherwise required, the Commission may administratively waive or amend any rule stated above as long as the change does not promote waste or jeopardize correlative rights, is based on sound engineering and geoscience principles, and will not result in fluid movement outside of the authorized injection zone. Standardized Language for Injection Orders Date: August 17, 2004 Author: Jim Regg Demonstration of Tubing/Casing Annulus Mechanical Integrity The mechanical integrity of an injection well must be demonstrated before injection begins, at least once every four years thereafter (except at least ünce every t\VO years in the case of a slurry injection well), and before returning._ª-.wcl1 to service folIowÎn.g aft€T a workover affecting mechanical integrity. and at ki1~;t once every /1 years white actively injecting. For slurry injectiorr--vrells, the tubing/æsffig-anftHfu-S-HHtS-t be tðskd tor mechanical integrity every 2 years. Unless an alternate 111èans is approved by the COlnnlisston. lnechanìcal integrity lTIUst be demonstrated by a tubin.g pressure test using a +fie M-I-+-surface pressure ofrnust be 1500 psi or 0.25 psi/ft multiplied by the vertical depth, whichever is greater, that ffHfSt-show~ stabilizing pressure that doesand Inay not change more than 10%- percent during a 30 minute period. -A:nÿ altenlak nlcans of det110nstrating -mechanical integrity mus-t:--Þ€-approv-ed by the COtnnlission. The Commission must be notified at least 24 hours in advance to enable a representative to witness pressure tests. Well Integrity Failure and Confinement Except as othenvise provided in this rule, +!he tubing, casing and packer of an injection well must deffionst;.-ate ¡naintaìn integrity during operation. \Vhenever any pressure conlmunication. leakage or lack of injection zone isolation is indicated by injection rate, operating pressure observation, wst, survey. log. or other evidence, t+he operator fBHSt-shall immediately notify the Commission and submit a plan of corrective action on a Fonn 10-403 for Commission approvat \\'henever any pressure cO!nlnunication~ leakage or lack of injection zone isolation is indicated by injection rate, operating pressure observation, test, survey. or log. The operator shall shut in the wel! if so directed by the Comnlission. The operator shall shut in the \vell \vithout awaiting a response tì-orn the ComIl1ission if continued operation \.vould be unsafe or would threaten contamination of fresh\vaterIf there is no threat to fresll\vater, injection lnay continue until the COlTIlnission requires the \veIl to be shut in or secured. Until corrective action is successfully cOlnp1cted, Aª monthly report of daily tubing and casing annuli pressures and injection rates must be provided to the Commission for all injection wells indicating pressure communication or leakage. Administrative Actions Unless notice and public hearing is otherwise required, the Commission may administratively waive or amend any rule stated above as long as the change does not promote waste or jeopardize correlative rights, is based on sound engineering and geoscience principles, and will not result in fluid movement outside of the authorized injection zone. .. .' [Fwd: Re: [Fwd: AOGCC Proposed WI Lang ): for Injectors]] ') $I:I.IJJect: [Fwd: Re: [Fwd: AOGCCProposed WI Language for Injectors]] FrQm:Winton Aubert <wiriton2aubert@adrnin.state.ak.us> l)~te: I?B~~,2,~O~tfO?1,q9:.4~':S'2:0§99 .... ." ". .......... .,. .'.« ,'. ............. .. . .TQ;..·Jø4yJ·qøloJJilþie~pdy~c;òlpÌÍ1bi~@aQmin~stat~,#lê~t1s.»,..· . This is part of the record for the Nov. 4 hearing. WGA -------- Original Message -------- Subject: Re: [Fwd: AOGCC Proposed WI Language for Injectors] Date: Thu, 28 Oct 2004 09:41:55 -0800 From: James Regg <jim regg@admin.state.ak.us> Organization: State of Alaska To: Winton Aubert <winton aubert@admin.state.ak.us> References: <41812422.8080604@admin.state.ak.us> These should be provided to Jody as part of public review record Jim Winton Aubert wrote: FYI. -------- Original Message -------- AOGCC Proposed WI Language for Tue, 19 Oct 2004 13:49:33 -0800 Engel, Harry R <EngeIHR@BP.com> winton aubert@admin.state.ak.us Injectors Subject: Date: From: To: Winton... Here are the comments we discussed. Harry *From: * NSU, ADW Well Integrity Engineer *Sent: * Friday, October 15, 2004 10:43 PM *To: * Rossberg, R Steven¡ Engel, Harry R¡ Cismoski, Doug A¡ NSU, ADW Well Operations Supervisor *Cc: * Mielke, Robert L.¡ Reeves, Donald F¡ Dube, Anna T¡ NSU, ADW Well Integrity Engineer *Subject: * AOGCC Proposed WI Language for Injectors Hi Guys. John McMullen sent this to us, it's an order proposed by the AOGCC to replace the well integrity related language in the current Area Injection Orders. Listed below are comments, not sure who is coordinating getting these in front of Winton/Jim. Overall, looks okay from an Operations perspective. We do have a few comments, but could live with the current proposed language. Note the proposed public hearing date is November 4. The following language does not reflect what the slope AOGCC inspectors are currently requiring us to do: "The mechanical integrity of an injection well must be demonstrated before injection begins, at least once every four years thereafter (except at least once every two years in the case of a slurry injection well), and * before*_** 1 of 3 10/28/2004 11:09 AM [Fwd: Re: [Fwd: AOGCC Proposed WI La ge for Injectors] returnj.ng a well to service following a workover affecting mechanical integrity." After a workover, the slope AOGCC inspectors want the well warmed up and on stable injection, then we conduct the AOGCC witnessed MITIA. This language requires the AOGCC witnessed MITIA before starting injection, which we are doing on the rig after the tubing is run. Just trying to keep language consistent with the field practice. If "after" was substituted for "before", it would reflect current AOGCC practices. It would be helpful if the following language required reporting by the "next working day" rather than "immediately", due to weekends, holidays, etc. We like to confer with the APE and get a plan finalized, this may prevent us from doing all the investigating we like to do before talking with the AOGCC. "Whenever any pressure communication, leakage or lack of injection zone isolation is indicated by injection rate, operating pressure observation, test, survey, log, or other evidence, the operator shall * immediately*_** notify the Commission" This section could use some help/wordsmithing: "A monthly report of daily tubing and casing annuli pressures and injection rates must be provided to the Commission for all injection wells indicating well integrity failure or lack of injection zone isolation." Report content requirements are clear, but it's a little unclear what triggers a well to be included on this monthly report. Is it wells that have been reported to the AOGCC, are currently on-line and are going through the Administrative Action process? A proposed re-write would be: "All active injection wells with well integrity failure or lack of injection zone isolation shall have the following information reported monthly to the Commission: daily tubing and casing annuli pressures, daily injection rates." Requirements for the period between when a well failure is reported and when an administrative action is approved are unclear. This document states "the operator shall immediately notify the Commission and submit a plan of corrective action on a Form 10-403". If we don't plan to do any corrective action, but to pursue an AA, does a 10-403 need to be submitted? The AOGCC has stated they don't consider an AA as "corrective action". Let me know if you have any questions. Joe -----Original Message----- From: Kleppin, Daryl J Sent: Wednesday, September 29, 2004 1:37 PM To: Townsend, Monte A¡ Digert, Scott Ai Denis, John R (ANC) i Miller, Mike E¡ McMullen, John C Subject: FW: Public Notices FYI -----Original Message----- From: Jody Colombie [ mailto:jody colombie@admin.state.ak.us Sent: Wednesday, September 29, 2004 1:01 PM Subject: Public Notices Please find the attached Notice and Attachment for the proposed amendment of underground injection orders and the Public Notice Happy Valley #10. Jody Colombie «Mechanical Integrity proposal. ZIP» «Mechanical Integrity of Wells Notice.doc» 2 of3 10/28/2004 11 :09 AM #8 Tom Painter Division Manager Canoco Inc. 3201 C Street Suite 200 Anchorage, AK 99503 / .... . (CO~ February 1, 1988 ".1 ~""f!'~ Mr. Chat Chatterton State of Alaska Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr. Chatterton: Conoco received 1 'ff] TO I r . ",J-["-;. dated July 8, 1987 from the Alaska Oil and Gas ConservatioÎl Commission (AOGCC) which exempted those portions of all freshwater aquifers lying directly below the Milne Point Class II injection activities. We plan to begin drilling some new wells within the Mile Point Unit in March, 1988. Our plans include the pumping of excess non-hazardous fluids that are developed solely from well operations or necessary to control the fluid level of reserve pits into surface/production casing annuli. In order to facilitate the above described plans, Conoco requests Administrative Relief under Rule 8 of Area Injection Order 10 to amend Rule 2 of the injection order to exempt the pumping of excess non-hazardous fluids into surface/production casing annuli from the stated requirements of Rule 2. Please contact Jim Dosch at 659-6336 you should have any questions. Yours very truly, ''')'' ,,,,;,.,/,:::"" ..- .....~ t~v/~/ ~lJ. Painter ( ~/f)i1sion Manager \1 00.21-02 #7 ~\"\EO Sr-4)'~ ..::> <S' -,;....{¡ ~ -- :t. ~œ~ o <C " ~ \<'..¡, '\~ l'-1( PRO,,\~0 U._IRONMENTAL PROTECTION A_V REGION 10 1200 SIXTH AVENUE SEATTLE, WASHINGTON 98101 ".,.c:::::. -côKfM" (;(1 // .~~~~. ~~ , R,·-S ~N' G"~ li~_____ t: .____ ¡ Sp.. ' ENG _,....r..~ --<q'G 'Ii:~ -;~i)jLLf ",-"î t,,__c ìf::~i6ð.<:'¿;~T"-1 '.. _'~~,' \j_,'-~~_~".j'::J '_.. . !Et~C1-'l\SS-_ --- I· .-----, ... - --. ..,.,.. , 1" T-'C I i:) I t.ii_ {t: ",' ,., A·" -'"F 1". ¡.".JllL ..!¡"_,.."1~ REPLY TO ATTN OF: JUL 0 21987 WD-132 (þ-f 0* i! W. W. Barnwell, Commissioner Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501-3192 RE: Conoco Incorporated Aquifer Exemption Request of May 1,1987 Dear Mr. Barnwell: Based on Conocols May 1,1987, letter and June 12,1987, supplemental, we believe the subject aquifers qualify for an exemption. In addition, I understand that Commissioner Lonnie Smith informed Harold Scott on June 25, 1987, that there were no comments during the public comment period regarding the proposed exemptions. Therefore, we concur with your decision to exempt the aquifers beneath the Milne Point Unit for Class II injection activities only. This is a "non-substantial program revision" in accordance with Section 13 of our Memorandum of Agreement. Sincerely, ~~ Robert S. Burd Director, Water Division #6 . . Telecopy No. (907) 276-7542 June 18, 1987 J~lj- ¡:µ.¿ ~ cJ #~. Robert S. Burd', ])i.reetor Water Division u.s. Environmetttal Protection Agency llegion,lO MIS 409 1200 Sixth Aventile Seattle, WA ,a'.un lle: Proposed Aquifêr Exemption far Milne Point Unit - Conoco Dear Mr. Hurd: Your May 27, 1987 letter requesting additional information, considered pertinent to the application for aquifer exemption was forwardèd to Conoco for their handling. Conoco's response to your queries is incorporated i11.their ' June 12, 1987 letter, copy of -.bieh is attached..' Canoco's response appears to bolster the CO'ffIItission'searlier opinion that the granfing of Conoeo's requested eXeJDþtion does not constitute a "substantial progratl revision". Accordingly" we would appreciate receiving your eoneurreDCesO that tne C~ss1on may proceed Wi.'é the draftî_g 0'1 an Aquifer Exemption Order to be issued in'eonf01l"Dl8l'lce wftlt20 AAC 25.440. Sincerely, h/W ".- w. W. Barnwell Commissioner Enclosures jo/F.WWB.34 c: Harold Scott, Seattle #5 Tom Painter Division Manager Conoco Inc. 3201 C Street Suite 200 Anchorage, AK 99503 -~J ~ ":t$ , 7Ii\ '~.",.\.-1.~- ~~. " ...": ~ , r .:: _~:, :;¡",.~:', ~r ~, . ., ",.~,. ,,,,,,~,.~_...,,",.....__. ,~.- , ' ~or :~ June 12, 19~ 7 Mr. Chatterton, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Chatterton: Supplement to the Application for Freshwater Aquifer Exemption - Milne Point Unit, Shallow (Tertiary Water) Sands On May 1, 1987 Conoco submitted an application to the AOGCC for an Aquifer Exemption of the Tertiary water sands located within the Milne Point Unit (MPU). As specified in both the State and Federal regulations an aquifer qualifies for an exemption if it meets the following criteria: (CFR 40 146.4 and 20 AAC 25.440) (1) Does not currently serve as a source of drinking water. Production operations at Milne Point were suspended in January of 1987. The Tertiary water source wells were shut-in at that time and will remain in a static condition until production enhancement operations are re-established. (2) It cannot now and will not in the future serve as a source of drinking water. As per AAC 25.440 (1) (B) and (C) it would be uneconomical to de- velop the Tertiary water sands, within the Milne Point Unit, as a source of drinking water. The cost to fabricate and install the 10,000 GPD water processing system at MPU was approximately $10 million (refer to May 1, 1987 report for details). If the system were to operate at 100% efficiency 365 days a year, the initial investment could be paid out in twenty years if the water were worth $0.36 a gallon (assuming 12% interest). This is 1000% higher than the current North Slope (KIC) price for water of $0.03/gal. RECEl\/EL) ~) LJ ,t\,',\ '),7 L ~., . .. ~ . ",,' fJ :; 41aska OiJ & G~..~ r'()" - C' «,:> V ¡ IS. ommissian Ancho¡éi~e f Conoco is not currently, nor does it plan in the future to Tertiary water for human consumption. Economics continuing with the current practice of hauling water from camp or surface lakes (when available). clarify dictate the KIC (3) The TDS content of the ground water is more than 3000 and less than 10,000 mg/1 and is not reasonably expected to supply a public water system. There are only three water supply wells within the MPU from which water samples can be taken. During the period of active operation at MPU the water source wells were operated for less than one year with only one well being utilized at any given time. Water sam- ples from the Tertiary source wells were analyzed infrequently and the results were often inconsistent. In the CFP-1 well, for exam- ple, tests indicated 2500 ppm TDS in a sample taken on 1-6-86 and 3162 TDS in a sample taken 1-3-86. In a test completed by Conoco's research department the total salt concentration for CFP-1 was 3260 ppm. In the B-1 well four samples have been an- alyzed with resultant TDS values of 3539, 3176, 3300 and 3160 ppm There are no test values available for the A-2A well. In it's current status, temporarily shut-in, no samples can be obtained. (Copies of available water analyses completed on water from the Tertiary sands are attached). Conoco is grateful for the expeditious responses by the representatives from both the AOGCC and the EPA. We hope that this letter will provide the remainder of the information necessary for your agencies to rule on the subject request. Should you have any further questions please con- tact Mr. n Girdler at 564-7637. DRG/vv I .'.... ¡,-....... ~ , , ~. . . , ...) ~, · , . .. Sample I.D.: B-1 Sample Point: Flowline DISSOLVED SOLIDS CATIONS Sodi1Un, N a (calc.) Calcium, Ca Ma{Desium, Mg Ban1Un,Ba TotAl Ç;:¡tions ANIONS Chloride, Cl Sulfate, SO, Carbonate, CO! Bicarbonate, BOO. Total Anions \, J mg/' 1194 130 6 1? 1342 1950 3 242 -ITg-=¡- Total Dissolved Solids (calc.) 3539 Iron, Fe (to\&1) Sulfide, as HIS 0" 7 REMARKS &. RECOMMENDATIONS: HS:jah CONOCO MILNE POINT WATER ANALYSIS REPORT }, Date Sampled: 9/25/86 Analysis By: Hal Stevens ANALYSIS RESULTS me¡l 51.9 6.5 0.5 D.? OTHER PROPERTIES ~:ecific Gravity, 60/60 F. Resistivity (ohm-meters) F. _ 7 : 8.1 l. 000 @ 780 WATER PATTERNS-wu/l STANDARD to 10 0 10 20 No I J J J II J 1 I J J I J 1 J I' I J J J J II J II J I 1II1 J I J J J J I 1 Cl 55.0 0.1 o 4.0 Co H II 1111 1111 1111 1111 1111 lilt, It II 1111 1111 H~ 11111111111 11111111111111111111111111111111 S04 f. till 1111 lilt till 1111 Iltt till Itll 11111111 CO¡ LOGARITHMIC No III~II I 1111111 I 11111" I 1111111 I 11111111 I 11'1111 111'1111 111'1111 C1 CD III~" i 11111"1 11111111 "11I1" f I 11)1111 . 11)1111 III)"" 111)11" HCO¡ IIg tllll" f 11111 II I 11111" I 11111"1,.1 II ~III I 11)1111 I 11)1111 t tlltllI so. , .~"I" · ~"'tJ I 'i"'" I !i'"I" · _' "·"2' "I"'ª I ",, 'I' "''''lcOa - - r'l- i,- ¡~." ~"..., ¡'"~~,,. ~ 1-~., .~..::. \'~"""¡ I~ ;, '....;L "'; ',; II 1 l~.¡as!(a 'C¡: ;~:. G~r~·· ~=:~) ¡-: ~~. (;0 ~-1': ~T~ ~ ':,~ ,:~~ ~ ~~ ~ /4 Sample I.D.: B-1 Sample Point: Flowline DISSOLVED SOLIDS CATIONS" Sodium, N a (calc..) Calcium, Ca Magnesium, I1g Barium, Ba Total Cations ANIONS Chloride, Cl Sulfate, SO. Carbonate. œ. Bicarbonate, BOO, Yng II 1085 142 3 .' . 8" 1211 . 1800 2 o 1"63 Total Anions" 1965 . ... . < ,.... Tot&] Dia&olved Solids (calc.) 3176 hon, Fe (1ota1) Sulfide, as IbS ~'7 . ) IŒI4ARKS . RECOHHENDATIONS: CONOCO MILNE POINT WATER ANALYSIS REPORT 'I Date Sampled: 10/17/86 Analysis By: Chuck Steube ANALYSIS RESULTS me/I 46 7.1 .3 . 1 50.7 . 1 o ··?6 ....,'.. '''.,.~.' ,.., "- OTHER PROPERTIES E:'cific Gravity, 60/60 F. Resistivity (ohm ·meters) 7..68 -1 .006 F. WATER PATTERNS-YM/l·· STANDARD to 10 0 10 to No IIII IIII II \ I IIII IIII IIII 1111 IIII 1111 t II I' Cl CD ·1111 1111 II II If II· 1111 1111 JIll 1111 1111 U II H~ .., 1111 1111 1111 1111 1111 1111 II II 1111 II II 1111 10.. F. 1111 JIll 11111111 1111 1111 1111 1111 1111 1111 r.o, . .. LOGARITHMIC liD 1U1i1l1 UUJII 1 11111" I HIII" 1 11111111 1 "11111 111'1111 111'1111 t1 c. tlt~Hi UII)III' tlIII" 1 fill" t 1"1"11' 111"11 '''11111 '''}\lII"COa III 'lI~tll IIII}II t ."111"1 11I1111 ~~'II~II t II~III t tt~1II t 111"11 so. " IIlItll I 4111I1111 ,,"111 I 1111'111 I ".)11 IIIIlIu 11111111 1111"'1 co, I ~.. ~ .2 . - 2 ª I I ..... '- I'..... \ ......" ~""; ........ ~ ".: \',..' ~. t,.ias,~(a ~"J¡; 8: :,~;L~S , . .. n\· CHEMICAL & &1iOLOGICAL LABORATORlbS JF ALASKA, INC. ANCHORAGE INDUSTRIAL CENTER 5633 B STREET ANCHORAGE. ALASKA 99518 TELEPHONE (907) 562-2343 Af~ALYTICAl REPORT: ..'"-,. ,,. '"-"'" .-- -...- . SAMPLE lOC^TIOl-l Milne Point~ RECVD. BY ETY lAB.# 4601 DA IE RECVD. 10/21/86 DA IT COMPLETED 10/24/86_ DA TE REPORTED 10/27/ß6 _........___.... SIGHATURE .n' .. ~ ... '" ._ ~~~~=.~.=.... . f.!D Il~DJCÀ TES · :Ol:E'''-o-rITC'TED' IUVOICE:: 4601 OA TE··10128/86 DETECTI01l lIì1IIIs')lrC) ~ = ====:::,.:= ===:=.=."=.~~~,,,~=':..=.= = = = ==:::: = = ='::: =:=='==== === = = = == = = = ='=~'====== = === == = = = = = = = =-= =.:::',=.= = == CUSTONER Conoco~ Inc. Milr)p Point. llnit DATE COLLECTED . 10/20/86 TltíE COllECTED 1500 .... SAMPLED BY C. S. SOURCE B- 1 Source Wa ter We 11 B-1 Flowline REMARKS MA TRIX .'~. . mg/1 )ALUl\llNUM. AI ( ) ARSENIC. As ) BARIUM. Ba'" . _..".. ,..... ..,·_,M..·.........,_ , -....-, - .....".'......- """-" ..~ ( ~) BORON. B... ' ) CALCIUM. Ca ( ) CADMIUM. Cd ( ) CHRÒMIUM,"Cr< ) COPPER. Cu . ) J RON. Fe: ) LEAD, Pb ) ~IAGNESIUM. Mg ( ) MANGANESE. Mn ND (a.OS) ...",... ."'-~"-- '..........-.. mg/1 .". ......-..... _.."..,,,. _.'~.... ,. mg/1 ( ) STRONTIUM. Sr 2.5 3300 ) TOTAL DISSOLVED .SOL.IPS. ..._.....,. '._._" . ) TOTAL VOLATILE SOLIDS.. "~".__.. ( ) SUSPENDED . ".. . ····SOLIDS ( ) YOlA TILE SUSPENDED SOLIDS" ( .) HARD~ESS AS CaC03 '" ( ) ALKALINITY AS CaC03 ) .. ,.....,,- "',....,.'..'.""...,..-.... '..._-".... " ..-,...-.-...-.-.,.....-- ,.".~ ND (0.05) ND (0.05) 0.051 N D . ( 0 ..05 t . ND (0.05 ).....-......-.(--) TIN,·Sn -'-' .. ......._,,~_....-~.....-.....'.....,..."," . .'~ '.. ~ """"""'-'~-.,... 6. 1 :-'.:"- -. "~=(:":J v J\-~.~J5IV~,1 ;..v -,.cr.....·......... ....".."..... .., ND (0.002)"..'···· ·'c' ) NO (0. 0 5 )...~:,..:..:.:_..._..(-- ) ND (Ò.05) "'0.077 135 0.82 ND (0.05) 20 0.21 ) ~1ERCURY. Hg . ND (0.05) ( ) NICKEL. Ni NO (0.05) ( ) PHOSPHOROUS. P 0.011 ) POTASSIU~I. K _ 10 ) SELE~IU~I. Sc NO (0.05) C ) SIUCO~. Si 6.2 NO (0.05) ) SILVER. Ag 970 ( ) SODIU~t. ~3 . ...."'_,,,...,0:_.,...... .~ . --( ) zlNe~ Zn" I~',·n· ,."",' .....'u.'..' "..., 420 122 ( ) ZIRCONIUM. Zr ) ( ) A~1:-'JONIA NITROGEN-N ) KJELDAHL . 'NITROGEN-N ( ) NITRA TE-N ********************** ( ) COLOR-UNITS ( ) NITRITE-N ( ) CHLORIDE 2~000 ( ) CYANIDE ( ) FLUORIDE ) OIL A!':D GREASE } PHE='Ol ) PHOSPHOROl!S . (ORTHO)-P ( ) SUL.fATE NO ( 1 ) ( ) SCLFIDE (H;S) _ ( ) CO:--:DUCTIVITY, umhos/cm ) lA~GLIER It'DEX 7000 ) lA~GlIER INDEX . ( ) pH. U~ITS 7.9 ) TL=RBIDITY. ntu «) COLIFOR~1/JOOmt ( ) ( ) ) ~ Sample I.D..: B-1 .~,~._-,. Sample Point: Flowline .' .,~.- .,. --'- ",.......~'...... .'.-"~, .' ..... DISSOL VEDSOLIDS . -.-.. '"" ",. - -, - "_._,,.~...... CA TIONS._. _."",g/L.. Sodium,..Na(c.alc.) ] 046 Ca1cium, Ca 138 Magnesium, IIg 11 Barium, Ba . In- Total Cations 1205 ANIONS Chloride, Cl Sulfate, SO. Carbonate, CO, Bicarbonate, BOO. 1800 4 o 151 1955 TotAl Anions Total Dissolved Solids (calc.) 3160 Iron, Fe (tot.a1) Sulfide, as ILS 7;85 REMARKS & REC<>MJrIENDATJONS: HS/jah ) , CONoeo MILNE POINT WATER ANALYSIS REPORT } Dat.e Sampled: 12-25.,..86:. ... Analysis By: Hal ANALYSIS RESPLTS mell . ""H·-45.1) 6.9 .. o. q . O. 1 50.8 0.1 o 2.5 " . -. ..,..-....-, -.". ,",. . HOTRER . PROPERTIES ....·11 ...---. ........... . l¡>ecific Gravity, 60/60 F. --Resistivity' (ohm-meters) F.- . 7.$1) . -1..,.Q.~ WATER PATTERNS-m-ell STANDARD to 10 0 10 20 No 1111 IIII IIII IIII III I IIII IIII IIII . III III I C1 Co 11 II 1111 II II 1111 1111 1111 1111 1111 1111 1111 "~ II, '1111 1111 liB 1111 1111 1111 II iI 1111 II 1'1 I i II so.. F. 1111 1111 1111 1111 1111 1111 11111111 1111 III' coJ LOGARITHMIC ~o III~III IIIIJII I 11111111 11)'1" I '"11111 I "1"11 11111111 1111"11 Ct· ." c. 11t~" i 11111"1 III~III '4 11I1 If t 111]1111 111111I1 1111"11 IUI"1! HCOa lAg 1Iul"1 lIul" I "'~" 1 111\1"1 .1...'11111 III~III 'I~~"I 'III~'.'~ so.. , ,¡"III I ~"'1" · i."'" 1211I1.. '_' "."2' "h,,ª I II hll~' ,,1"ïO¡ ¡.~.~ ~.:.',~: '~( ( fl ~ V [¡¡,) . j ;>~,¡"1. ~~: \~¡ -j: ., ¡,'....~I·' ,--',-,,,.,, ('nl"7'1n-!i~S"-I'''' A\clS~'(.B. Oi; é~ \:jC:.~,ì \.~\.I ¡':'~1' ,.1\", !Hi~~:.J1.. ~,.,.~: =========================================================================== 9.7 175 3.9 7.76 110 (Continued) INORGfu~IC CHEMICAL CONTAMINANTS: Arsenic mg/l 0.005 Barium mg/ l':~.·":~:'''=.-··---- ~~~~~·Z9·--.-.:· Cadmium mg / 1. _"." ...."...,."". ,.Ü..022,. ._"". Chtomium rng/l ..,,------..----,- ··<..g·.·O§,~·_·,··- 'Fluorrde'" ..~/ 1 -.."..." ----. ·,·.,·..(,..~1g-"·· ." ~_.. ~ïkâa:~." .~~~.~.._-~..:..jii:i/ 1 '.:..: ::."~'~~~.:"."- J).~."Q[4': '.-"~.'~. Mercury mg/l 0.0007 Nitrate-N mg/l <0.10 Selenium rng/l .,........... ........ <0.002 Silver mg/l 0.02 SECOl'IDARY CONTAMINANTS:·· .... Chloride rng/l ..---.....----" 5029 Color C.U. @ pH 60 @ 8.5 at 17.7 deg. C Corrosivity " Aggressive Index. Alkalinity mg /1 as CaC03 pH pH Units Hardness mg /1 as CaC03 Iron mg/l Manganese mg/l Sodium mg/l Sulfate rng/l Total Dissolved Solids mg/l MISCELLANEOUS: Turbidity NTU Calcium mg/l Strontium rng/l Carbonate rng/l Bicarbonate rng/l 1 0.04 1 500 0.3 0.05 250 250 0.02 <0.01 27 <1 10026 678 2.08 0.20 849 24 6.5-8.5 118 8.5 at 17.7 deg. C Noncorrosive 250 15 . ..,........ \"::·,"\I~"·;·· ........,. '... 0.05 1 0.010 --0".05 .... 2.4 "'.' -0.05 0.002 1Ö .,.0.01 0.05 <0.01 ...._....."'.".....'~.,......_....'Io,i,,.'..'. 0.001 0.0003 0.0134 ... .,' ,..~"'."._......,....,.... '.1 '.' 0.001 0.31' 0.004 -, ,-"". '.,'.-""'-" .\._,~...~.__._.,,-.,..-. .',,-..,'......'¥, ..... ....,..,..~ =========================================================================== .....- '..'"- ....... 13.4 (Scaling) ·ADEC M::JC* . Result·, Standard Deviation ·Parameter· -.- .. Unit 041285-1 ,.Sampl~" .J.P. # : --------------------------------------------------------------------------- ---------------------------------------------,------------~----------------- .... '.. w . ....."._ '.. Source: MPUCFP No." l' Wellhead a'._......·_'..." .,..-, ....-.-....,-.,. ,,,"-"~' Date Arrived Time Arrived Date Sampled Time Sampl ed ~ ,'. 'Datè Completed: 04-12-85 0915 04-11-85 1620 04-23-85 907·479 3115 FAIRBANKS, ALASKA 99701 -....."., ~.-..'''.........,., ._..",.~_., ,..- Chuck Stuebe Attn: Client: CONOCO, Inc. Address: POUCH 340045 PRUDHOE BAY, ALASKA 99734 600 UNIVERSITY PLAZA WEST. SUITE A ( NHRTHERN TESTING LABORATORIES, INC. -~I'¡ '" '\ ~~/~' < ~/'~ )1 ( "". f NORTHERN TESTING LABORATORIES, INC. 600 UNIVERSITY PLAZA V,¡ESì. SUITE A FAIRBANKS. AL.ASKA 99701 907479 31'5 Client: CONOeD, Inc. Date Arrived 05-01-85 Address: 2525 C Street, Suite 100 Time Arrived 0915 Anchorage, Alaska 99503 Date Sampled 04-30-85 Time Sampled Attn: Jim Dosch Date Completed: 05-09-85 Source: MPUCFP No. 1 Wellhead Sample ID # : 050185-1 Parameter Unit -------------------------------------------------------------------------- -------------------------------------------------------------------------- ADEC MCC* Result Standard Deviation -------------------------------------------------------------------------- -------------------------------------------------------------------------- INORGANIC CHEMICAL Arsenic mg/l Barium mg/l Cad'mium mg/l Chromium mg/l Fluoride mg/l Lead mg/l Mercury mg/l Nitrate-N mg/l Selenium mg/l Silver mg/l SECONDARY CONTAMINANTS: Chlor.ide mg/l Color C.U. @ pH Corrosivity Aggressive Index Alkalinity mg/l as CaC03 pH pH Units Hardness mg/l as CaC03 Iron mg/l Manganese mg/l Sodium mg/l Sulfate mg/l Total Dissolved Solids mg/l MISCELLANEOUS: Turbidity NTU Calcium mg/l Strontium mg/l Carbonate mg/l Bicarbonate mg/l CONTAMINANTS: 0.014 4.4 0.014 <0.05 0.23 0.010 <0.0002 <0.10 0.007 <0.010 2685 35 @ 8.1 0.003 0.2 0.001 0.05 1 0.010 0.05 2.4 0.05 0.002 10 0.01 0.05 0.001 0.0025 0.001 250 15 12.8 (Scaling) Noncorrosive 120 8.1 at 23.1 deg. C 410 1.24 0.16 770 8.8 4980 7.6 103 1.8 o 120 6.5-8.5 0.03 0.01 4 0.3 0.05 250 250 500 1 1 <0.1 =======================~================================================~= (Continued) , .,' r· .!:' "",If; ~_!,EMICAL & Cr=-1¡GIC1L LABORATORIES' 'JfLASKA, INC. ~ . TELEPHONE (907) 562·2343 . ANCHORAGE INDUSTRIAL CENTER' -. .' ...'t'OIII'U 5633 B Street T ANALYTICAL REPORT STOMER Ccnocx:>, Inc. Mime Point SAMPLE LOCATION: , ": E COLLECTED 6-10-85 0700 RECVD.BY FOR ~~B US~~N~Y 8786 DATE REPORTED SIGNED ~~~ ~ ,'F't9;L mg/1 []Tota1 Dissolved 3430 Solids []Tota1 Volatile Solids []Suspended Solids []Vo1atile Sus- pended Sol ids []Hardness as Ca C Ûi []Al kaT inity as CaC03 [] []Lang1ier Index @ 400p 0.037 []Lang1ier Index @ 1400p 1.1 TIME COLLECTED: SOURCE :'~PLED BY Fox DATE RECEIVED DATE COMPLETED MARKS mg/l mg/1 Ag,Si1ver []P,Phosphorous []Pb,Lead []Pt,Platinum []Sb ,Antimooy []Se,Selenium []Si,Silicon []Sn,Tin []Sr,Strontiurn []Ti,Titaniurn []W,Tungsten []V,Vanadium []Zn,Zinc []Cyanide []Sulfate []Phenol A 1 ,A 1 urn; n urn As,Arsenie Au,Go1d 5 ;ron Ba , Ba r ; urn 3.9 Bi,Bismuth :a ,Ca 1 e i urn 48 :d ,Cadmi urn <0.001 :o,Cobal t Cr ,Chromi urn :u ,Copper ~e,Iron 1.7 []Zr,Zircon;um [] * * * 6-10-85 6-18-85 6-18-85 182 * * ig ,Mere ury * []umhos Conductivity 4,400 8.15 []Arrrnon i a Nitrogen-N [] Kj ed a h 1 Nitrogen-N []Nitrate-N []Nitrite-N []Phosphorus {()--tho) -p []Chloride []Fluoride (, Potass i urn []pH Units 19,Magnesium 15 []Turbidity NTU []Color Units [] .Coliform/10Oml [] [] 1n ,Manganese 0.15 \ 10 ,~o lybdenum 2000 ~a , Sod i urn 1030 U .Nickel 4.9 50 /}3 .., r-. ./ ( .075 <. :!5 <. :!5 ( . 10 1 .2 < .025 <'50 ( .O:!S .; .0:!S NICKEL (NI) lEAD (PB) ANTIMONY (SIn TIN (SN) STRONTIUM (SR) TITANIUM (Tl) THALLIUM (TL) VANADIUM (V) ZINC (ZN) {.030 <.15· .073 { .005 <.015 (.030 .021 .088 . 1 1 (.050 SILVER (AG) ALUMINUH (AL) BORON (B) BEF.;YLLIUH (fiE) CADMIUM (CD) CHROMIUM (CR) COF'PER (CU) I F:ON (FE) MANGANESE (HN) MOLYBDENUM (MO> HG/l MG/l TRACE ANALYSIS - -. OTHER ANALYSIS NA _880 (MG/l) _..w _ .,.__ ~_." .,- .--,- ",,_."~.- - 'n ..~._ ._..._ SPEC I F"I C GRAVI T Y : 1 .003 RESISTIVITY AT 3000 DEG F' 1 .580 OHM METERS PH: 7.60 '-"" ,HEQ/L HG/L HEQ/L MGIL TOTAL SALTS 3260 SODIUM (NA) 49.1 1130 HYDROGEN SULFIDE 0 POTASSIUM (K) CHlO.R,IDE ,( CL) . ...... 52.6 1870 .... .....HêGNESIUM (MG) 0.9 17 SULFATE (S04) 0.0 ") CALCIUM (CA) 4.5 90 .:.. CAF:BONA TE (C03) 0.0 0 BARIUM (BA) 0.0 3 BICAF..'ftONA T E" 'fHE03-) 2.4 148 .- IRON (MG/l) TOTAL 0. DISS. 0.0 HYDROXYL (OH) SUSPENDED SOLIDS 2.5 ANAlYS~SRESULTS, _ _.. ..____u..·,,·_., "__""__"'_'_"'''_'_' .".._ . ~.,...".. -...........-.. ~".- FORHÄTION~ PRINCE CREEK COUNTY: NORTH SLOPE BOR COUNTRY: ,,,_ _ ,_,_, .... .PATE COLLECTED: 06/96/85. FIEt:1)';- HILNE"-POINT DEPTH: STATE: AK ._.$AIjF'LE. fQINT:$!-IF'f'L Y WELL HEADER IDENTIFICATION: CFP ~1 SUPPLY WATER ..." ,--....-,.'.- , . .,'~, .. -." \J9032 .,.~,.."-' ~-~.......,,_...._,.,.. .-.... -.,.,.,". .,-- ..-.........-...-.' ...,. "...~.~...__._~.....- PONCA CITY, OKLAHOMA . C()NOCq U-!ç. .uf'RODUCIIONJ;:ESEARCH DIVISION· WA IE R .ANAL't S lS...REF' aRT .. __h.,,_ ".._,_...~_.,~...". ~.".~.._~." "._ ."_..__._...~.._ .......__..__. ._____~.c·,_....·__·~___.......__ ._...~...... _.-...- . .......- ....-,-." -,,,~_._'''''' __.__.SVPpL Y W ^ TER FROMMI.LN.E..P.01NT_UNIT CFP WELL NO.1 . .. ..~.~..-. ."... ..' " W.AIt:.!t ANALYSIS REPOR t. . ...,.......... . .-- -"-<,._-_......_,."..~~..... TABLE 5 RR No. 102-2-5·~'5-85 Page 12 -'" ',~-' ) . ): ..~./ ~HEMICAL & GF~fGICAL LABORATORIE(,) J } ALASKA,_~NC. ~, ' " , ' TELEPhùNl:(907) 562-2343 ANCHORAGE INDUSTRIAL CENTER _ :~ _ 5633 B Street , ."I.~:~\ . ~,,,·cu"" ~ ANALYTICAL REPORT CUSTOMER Conoco, Inc. SAMPLE LOCATION:Milne Point Operations Center DATE COLLECTED 12-5-85 TIME COLLECTED: 1330 RECVD. BY FOR MB US~~BN~Y 1512 SAMPLED BY H. Stevens SOU8CE ~1M)D58 DATE RECEIVED 12-6-85 REMARKS Extremely hard, Alkaline water with high Iron & DATE COMPLETED 12-12-85 Manganese. 12-12-85 DATE REPORTED SIGNED ,-~1vw1 C. ~ mg/1 )ALUMINUM, AI <0.05 ) ARSENIC, As <0.001 ) BARIUM. Ba 5.2 )BORON,B ) CALCIUM, Ca 84 ) CADMIUM, Cd <0.01 ) CHROMIUM, Cr <0.05 ) COPPER. Cu <0.05 ) IRON, Fe 1.5 ) LEAD, Pb <0.05 ) MAGNESIUM, Mg 14 ) MANGANESE, Mn 0.13 ) MERCURY, Hg 0.0005 ) NICKEL, Ni ) PHOSPHOROUS, P 0.14 ) POTASSIUM, K 13 ( ) SElENIU~1, Se <0.001 ) SILlCO~, Si 3.8 ) SILVER, Ag <0.05 ) SODIUM. ~a 780 PS 26698 mg/1 mg/1 ) STRONTIUM, Sr ) TOTAL DISSOLVED 2560 SOLIDS ) TIN, Sn ) TOTAL VOLA TILE SOLIDS ) VANADIUM, V ) SUSPENDED SOLI DS ) ZINC, Zn 0.07 ) VOLA TILE SUSPENDED SOLIDS ) ZIRCONIUM, Zr ) HARDNESS AS 270 CaC03 ) ALKALINITY AS 110 CaC03 ) ) AMMONIA NITROGEN-N ) KJELDAHL NITROGEN-N ) NITRA TE-N ************************ <0.10 ) COLOR-UNITS ) CONDUCTIVITY, 3800 umhos/cm 1600 ) LANGLIER INDEX ) LANGLIER INDEX ) pH, UNITS 7.7 1.2 ) TURBIDITY, ntu COLIFORM/looml ) NITRITE-N ) CHLORIDE ) CYANIDE ) FLUORIDE ) OIL AND GREASE ) PHENOL ) PHOSPHOROUS (ORTHO)-P ) SULFATE r.~lf' I' - ~~, ~ t:= " ~,.'''\ ','-' ; ,þ R...., \. ,. " ..... ,:,"'" ¡r'\ ':- ! J i.u~'t. ~~ <1.0 ) SULFIDE (HlS) .J lJ :\; 1 ~:,¡ Alas!,a OJ¡ Bl G2S Cons" Comm¡ss\o~ J\nehon:(~)e J 0 , . \ '. '" , -,,'~~-~-" ~.,~..-,,,, ,~.". -. .... -, ._ "._".w......··, .,,,..., . ".' ., \\P1-W AtERc:ANAL1~SlScREPORl ~f I Legal Description I Well - I· Depth CFP- Type..of Water (Produ'ced, Sü'pp])', etc.) SampJing Point ,~o tl ¡-¿·c··· 'Wä'-'¡-e I" ·1Þ1,!jd,·-....~e- F I~ It! 1,"11 e··.. DISSOLVED SOLIDS'" ...... ... ....---. '··OTHER PRÒPERTIES CATIONS -- . mgll -'''mëll '-'... -"'~:~cÚi'c Gravity, 60/60 F. Sodium. Na (calc.) IOg3·- ·'t'.1 ..·-Resistivity (ohm-meters) Calcium, Ca q I- 4 ' fJ . r.. u ,. b ¡fI,'.¡ y Magnesium, Mg -- I Cf 1 ,~. u 2 Barium,Ba 4 D.I Company Co nO CD Fie1d rl) ., () fir, ne roìn+ Lease or Unit I SampJr No. I Date Sampled 1-3-~b I County or Parish I State Fonnatjon Water, BID Pr;n c., f:. CY~ek. / '3 onD .....-.-........... ... ... ... . ).. .-...---- SampJed By H ~! .. SI-t'£Iel15 F. ,.q 1~'O() ~ 5""/ 4 },/ T lJ .~ ANIONS Chloride, Cl Sulfate, SO. Carbonate, CO! Bicarbonate, HCO. I~?. 0 o o /40 5/. ?J o Q' - ;¿,:'i - . ,,~,... WATER PATTERNS-null..····--_· STANDARD 20 10 0 10 20 No ._...I,!,..:-4~.¡~-I.i~:'.I.¡\r:,~~ I:I.~ ~:...t:t~I.1 '1 It I '.r' . '" C~ Ca lilt IIII Jill ·~·:d'~r~'íli lilt JIll fill HC03 . ~g If II, 1111 II II 1111 f ~~. fill 1111 If II 1111 1111 504 i F. III I I I I I I I I I IIII I II.' I I I I I I I I I I I' II I I I I I I CO! . -..~ . Total Diasolv~d Solids (calc.) 3 16;L .. a III~ II I LOGARITHMIC I ¡ 1111('11 11"1" I I "11111 I 111"11 11111111 11I~I'h C1 Iron, Fe (total) Sulfide, as fuS I " b .' ~""..~,.__.. .. ,,-- . Ca 11111" i IfIlJIII ,,"JIII I ~ I 111)1111' "1"11 11111111 1IIIIUt HCO¡ Mg ""¡II f 111110 I /11I1"1 IIIIJII}' .1111"11 III)UU 1111"11 111111I1 so. f. ~""" ~~"'''' I ª" I" 12111'" t. II h"k' III"'~' III" '~ I IIIII'lCo, REMARKS & RECOMMENDATIONS: #4 u. '- )VIRONMENTAL PROTECTION ~,A.bv ~ REGION 10 ~ n 1200 SIXTH AVENUE ~ rJ ~ SEATTLE, W. ASHINGTON 98101 . (¡ . ( I . U MAY 27 17 ~~ ' 'P' r-- f/ /' _\\~E.O sr-4l: ~'<;' ~IS' jftt, ~~~ o "'{" '\ ~ ~-1- .\:~ l''''I1. PRü''{~V REPL Y TO ATTN OF: WD-132 '~1 -.--...- ..w, 'jl,. I." ",,--':'¡<¿ . ""-,_.~; !::':1;.:(~~ j_" I., "':' "', .1 .. . I ~' .. ':-, ':",:",~.t';;,'.~, \G ! ' ," ,I"~,: ¡ .J;.o.-- i,'.,:·,,{)1' "...,....~:,;~..~.\-' ~ ,." ,. '\., ;- :,:'~: ~,"I \ . : l_"..,......·· ." ." "...".., ...._-.."'~~_........,,"',.. I~.. r" ( ~'" ~ .~ ,1 ¡," ¡ ,.II w·' "". '~.." I! \.~ t ~, to ' ,l ~." f¡"j w. W. Barnwell, Commissioner Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501-3192 ..r L ,iì (' RE: Proposed Aqu i fer Exempt i on for Mi 1 ne Poi nt Uni t--ConocoA.laska Oil & Gas Cons, Gomrnlssion Anchorage Dear Mr. Barnwell: On May 13, 1987, we received your May 8, 1987, letter regarding the proposed aquifer exemption for Milne Point Unit. At this time, we are uncertain as to whether the exemption would be a "substantial" or "non-substantial" program revision. Our uncertainty centers around the following two issues: 1. There is inadequate documentation of the TDS levels in the water column areally throughout the Unit to determine whether the ground water is greater than 3,000 mg/l TDS. NOTE: Laboratory analyses submitted by Conoco show the CPF-l well has a TDS level of 2,500 mg/l. 2. The exemption does not appear to be related to a permit action nor to be an existing enhanced recovery project authorized by rule. According to the Federal Register, a major exemption is one with a TDS level of less than 3,000 mg/l and not related to action on a permit or not an enhanced recovery project authorized by rule. A major exemption requires a "substantial" program revision under 40 CFR 145.32. Aquifers with TDS levels greater than 3,000 mg/l and not related to action on a permit are minor exemptions processed under our-Memorandum of Agreement. Excerpts of the preambles to the Federal Register dated September 2, 1983, and May 11, 1984 are enclosed. In order to evaluate Conoco's request, the following information is needed: 1. Documentation of the TDS levels in the water column at several locations throughout the Unit. At a minimum, laboratory analyses for the source well (A-2A) and calculations of TDS levels (e.g., based on SP logs and Archie's equation) should be provided to show vertical and areal extent of TDS levels throughout the Unit. Enclosed are correspondence between EPA (December 24, 1984) and Conoco (May 15, 1985) illustrating the type of documentation that '} 2 could be used. Conoco's May 15, 1985, letter documented that their injections were not into underground sources of drinking water (less than 10,000 mg/1 TDS). EPA did not require extensive documentation of TDS levels for these shallow aquifers at that time because they were to be used as a drinking water source. 2. Documentation as to whether the exemption is directly related to a permit action or in an area authorized by rule. Also, what wt11 be the source of drinking water for the employees if the aquifer is exempted? It would also be helpful if the approximate capital and operation and maintenance costs of the alternate source could be provided. This could help demonstrate that using this aquifer for potable water is, in fact, prohibitively expensive. I have kept a copy of Conoco's May 1, 1987, letter to AOGCC and am returning their original letter to you. If you need additional information, please call either Daniel Steinborn at (206) 442-1225 or Harold Scott at (206) 442-1846. Sincerely, ~JvJ Director, Water Division Enclosures #3 ) Notice of Public Hearing STATE OF ALASKA Alaska Oil and Gas Conservation Commission Re: The application of Conoco Inc. for a freshwater aquifer exemption order for the Milne Point Unit. The Alaska Oil and Gas Conservation Commission has been requested, by letter dated May 1, 1987, to issue a freshwater aquifer exemption order for those freshwater aquifers existing beneath the Milne Point Unit, Kuparuk River Field. A person who may be harmed if the requested order is issued may file a written protest, prior to June 1, 1987 with the Alaska Oil and Gas Conservation Commission, 3001 Porcupine Drive, Anchorage, Alaska 99501, and request a hearing on the matter. If the protest is filed timely and raises a substantial and material issue crucial to the Commission's determination, a hearing on the matter will be held at the above address at 1:00 PM on June 16, 1987, in conformance with 20 MC 25.540. If a hearing is to be held, interested parties may confirm this by calling the Commission's office, (907) 279-1433, after June 1, 1987. If no proper ¡rotest is filed, the Commission will consider the issuance 0 the order without a hearing. -/ tJ~) ¡ ~ (L-'f /' 0' ~vl Lonnie . Smith Commissioner Alaska Oil and Gas Conservation Commission Published May 15, 1987 STATE OF ALASKA ADVERTISING ; ORDER ADVERTISING ORDER NO. AO- 08-5589 F R o M Anchorage Daily News P. O. Box 149001 Anci"Drage, Alaska 99514-9001 AGENCY CONTACT C''téil yn Evans DATE OF A.O. r-1"ay 14, 1987 PHONE (907) 279-1433 DATES ADVERTISEMENT REQUIRED: T o p U B L I S H E R Alaska Oil & Gas Conservation Com:ni.ssion 3001 Porcupine Drive Anchorage, Alaska 99501 Hay 15, 1987 $(1'0 ~~ SPECIAL INSTRUCTIONS: AFFIDAVIT OF PUBLICATION UNITED STATES OF AMERICA STATE OF~· 3/-, REMINDER- ss INVOICE MUST BE IN TRIPLICATE AND MUST REFERENCE THE ADVERTISING ORDER NUMBER. A CERTIFIED COPY OF THIS AFFIDAVIT OF PUBLICATION MUST BE SUBMITTED WITH THE INVOICE. DIVISION. BEFORE ME, THE UNDERSIGNED, A NOTARY PUBLIC THIS DAY PERSONALLY APPEARED ~ WHO, ATTACH PROOF OF PUBLICATION HERE. ADVERTISEMENT, OF WHICH THE ANNEXED IS ~ TR~ COPY, WAS PUBLISHED I SAID PUBLICATION ON THE /~ DAY OF ___ 19~, AND THEREAFTER FOR ð " " ,",' ,',' :,'. ,''''. ;'. :,,-:',:.' 'Notice..of~~blc~e~l',l~~. ........,; STATEOI7ALÄ$~A., ..... . ,',:. ,.AI&Ski¡l,QiI a~cI(;as,.:' ",<." .,..,ç9:~sel'¥~U~ns·~fl,ro·!.~~l~?'i\,,~\¡~¡ij; Re: The appll:atlc)n..C!fc:ono.co··· . Inc..for a fres~w~ter aqulfe~ ',." exemp.tlono~c;lt:ll'lf~r, t~e Milne" polhtUnlt. .¡, , : ,.:::. The ·);laSkaC)tI~ndG~S,Cón~er<.: vatlon.. CQl1Imlsslon hàsbeen.\,:';~· requested, by I.etter dllted May" 1, 19$7, tols$ueafr:eshw.ate~.'.:: aqllifer eXt!ll1ptløn: Order.'fø"''!!' thosefreshwafer :aCluifer.s e~.ls'-..: InQl,:leneath:the ..lV\lIn~. ~o~.n~¡,,:.,: Unit, . Kuparllk.. RJvet.fl~I~~,.: .!~. . Apersõ" who may. be.harmêcl'; If therequestedoi'øerIS)ss;ùed: may .file. i¡lVfrltte.n . protøset,.:. prior to June' 1, 19~7· with the' Alaska 011 and' G'es Co!,\serva,· tlon Com.mls$Jon~ 3001 Porco', pine Drive, Anchorage, . þ,laska' , 99501, and request'a hearlng.on'.. the matter.lftheprotest··is, filed. timely 'a~d ·.raises .a. S!IÖ-" stantial and ,naterUl1 .Issue c~u~, cia I to the'C.OlTlmISslon~~de"t.r:,:, :~,::::onWllr ::a~:.~. .~~. ,~: above address .at 1 :.00 p~ ':O~. June 16, 1987, In. conform.n~e ~ith .20 AAC25~~~! If. a..htsrJnø Is tQ be held, Interestecj",paH1es may confirm thlsbycallingttle Commission's office,. (907)· 27c9- 1433, after June 1,1987, If.~". proper protèst. Is flied, the Commission will consider the Issuance of tbe Orderwitho~.a hearing. '. Is/Lonnie C, Smith Commissioner' ,', Alaska Oil and Gas' Conserva~ fion Commission Pub: May 15, 1987 AO-08-5589 BEING FIRST DULY SWORN, ACCORDING TO LAW, SAYS THAT HE/SHEISTHE ~'l OF~~ ~M/"\/ PUBLISHED AT~:/;/;, -' IN SæD DIVISION ~ AND STATE OF ~4f1t.J, -AND THAT THE C~IV AYS, THE LAST PUBLICATION APPEARING ON THE l5(.-t\fJAY OF ~. 198".>, AND THAT THE RATE CHARGED THER~S NOT IN EXCESS OF THE RATE '- C~ PRIVAT~'::UAL~ f'-d~-~ ~.Jt~ ~ SUBSCRIBED AND SWORN TO BEFORE ME THIS 2LDAY OF I\AC(I.'3-- ~9S-l ft\ I (gj ~ C.e. i2)-{(>(]O~\J-I" NOTARY PUBLIC FOR STATE OF MY COMMISSION EXPIRES_ -_Ion (~~irOil tkf Col'\'lml_1 . t~ '8, \"?ß9 02-901 (Rev. 6-85) PUBLISHER #2 ",~""..'" _.~,.-...-" ...,.~"...~.~._... ) }' " Telecopy No. (907) 276-7542 May 8, 1987 . \ Mr. Harold Scott U.S. Environmental Protection Agency Region 10 MIS 409 1200 Sixth Avenue Seattle, WA 98101 Dear Harold: In accordance with Section 13 of ou.r 1986 Memorandum of Agreement covering Class II wells, Underground Injection Control, please find enclosed, for your revip,w and response, an application by Canoco for an aquifer exemption in the Milne Point Unit. .. We believe the application more than adequately justifies exemption of these aquifers, and that such exemption does not constitute a "substantial" program change. Please ådvise. Sincerely, 15' I It í5-::À (" h \..1 e II w. W. Barnwell Commissioner Enclosures: 1. Original application for Aquifer Exemption - Milne Point Unit 2. Copy of application for Aquifer Exemption - Milne Point Unit jo/F.WWB.26 #1 ~"._.,_,.,."...,_,.___"ft~¡,·" COMM '~ -'",'''''':''''".''' 'Jcy COMM '"1~ 1ß~ i :,_! ~ ~:' :.:::':. ,iQ+li j "-,~,, r'-''' .~ ~or 1CO) ) Tom Painter Division Manager Conoco Inc. 3201 C Street Suite 200 Anchorage, AK 99503 May 1, 1987 Mr. Chatterton, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 j') ~,~' ("" f' I ~ ,II ~¡¡..., Do. ,t '1"" '~I ~ y¡ ~I. L~ <4uU.~ 1tJ í: ~.r~' _. B .1~:;H7 Dear Mr. Chatterton: Aladm Oil & Gas Cons. Comm]::;:sion .ll\nchcra,iJ\3 Application for Freshwater Aquifer Exemption - Milne Point Unit, Shallow (Tertiary Water) Sands Conoco requests a "Freshwater Aquifer Exemption" for the Shallow Sand formations located within the Milne Point Unit (refer to Attachment I). These formations are a continuation of the Shallow Sands encoun- tered within ARCO' s Kuparuk River Unit. The EPA has previously granted an Aquifer Exemption to ARCO for the Shallow Sands through CFR 147.102(b)(3). Conoco requests the Freshwater Exemption under. State regulations 20 AAC 25.440(1),(B) and (C) which state that a Freshwater Exemption can be issued by the Commission if the water cannot be produced, as a drinking water source, economically. Total Dissolved Solids content of the water produced from the Shallow Sands at Milne Point, qualify the formations as fresh water sources, however, the chloride content of the water exceeds the maximum limit for potable water, as established by the State of Alaska, by nearly 800%. In addition, hydrocarbon gases are associated with the produced water. Though not currently operational, Conoco has installed highly techni- cal equipment at Milne Point to condition the Shallow Sands water for use as potable water. Conditioning the produced water requires a separation vessel, a reverse osmosis (RO) unit and an in-line filter. The equipment was expensive to install and has been more difficult and expensive to maintain than originally anticipated. Initial investment for the RO unit was $100,000 while the drilling and completion of the water source well cost an additional $2,500,000. The vessel (tank) used for separating out the produced gas has to be lined with a corrosion resistant material and heated to prevent freezing, estimated cost is approximately $500,000. The RO unit is rated for 40% recovery, which means that for every ten barrels of water processed, only four are drinkable while six barrels are waste water that must be disposed. Handling the waste water requires an injection well and the associated surface equipment. Investment costs for the waste water handling system at Milne Point exceeded $5,000,000. In summary, Conoco's efforts to process the Shallow Sands water have included an initial investment in excess of $10,000,000. This does not reflect the cost of storing and transporting the treated water or the facility operating costs. Conoco's water handling system was installed in the spring of 1985. Since that time the system has seen minimal usage as a result of processing complications. The RO unit installed at Milne Point is rated for 10,000 gpd but to date, only 650,000 gallons have been processed. Based on Conoco's experience with processing Shallow Sands water for utilization as drinkable water, there is no doubt that the development of the Shallow Sands, as a source of drinkable water, would be uneco- nomical. DISCUSSION The Shallow Sands in the Milne Point Unit, referred to as the Upper Cretaceous and the Tertiary formations (refer to Attachment II), consist of twenty-two individual sands. The regional structure of the Shallow Sands is a monocline, dipping gently to the northeast. The Shallow Sands within the Milne Point Unit contain significant volumes of heavy oil, located primarily within the Upper Cretaceous sands, while the shallower Tertiary sands predominantly contain fresh water (less than 10,000 ppm TDS). It is widely accepted that these reservoirs are not open to recharge by fresh water from the surface because of the extensive overlying permafrost which extends from surface to an average of approximately 1850' (true vertical depth), in the Milne Point area. Conoco currently has three water source wells located within the Milne Point Unit that are completed in the Tertiary formation. :,;;, ".~ t~ ,"""I A~{~:,~ \ê~ :~' l' "~,~ ~ ~ I, l.. /-·~.nL\} ; WELL SURFACE LOCATION PERFORATIONS (TVD) MPU A-2A 2031' FNL, 1585' FEL 2856'-2864' Section 23, T13N, R10E, 2874'-2912' Umiat Meridian 2935'-2980' 2983'-3023' MPU B-1 214' FNL, 4235' FEL, 2902'-2935' Section 19, T13N, RIlE, 3100'-3154' Umiat Meridian 3193'-3262' MPU CFP-1 303' FSL, 2075' FEL, 2758'-2777' Section 24, T13N, R10E, 2991'-2825' Umiat Meridian 2868'-2877' 2930'-2954' 2987'-3045' 3059'-3146' These wells were permitted by the Department of Natural Resources - Land and Water Management to produce up to 18,000 barrels of water per day (each). The water produced from these wells is injected into the Kuparuk River Formation as part of Conoco's enhanced recovery program. The Shallow Sands, within the Milne Point Unit, are protected by surface casing that is run to ±4600' TVD on all development wells. This is over 1,000' (TVD) below the base of the water sands. Surface casing strings are cemented to the surface to prevent cross flow behind the casing. Aquifer Geologic Description The Tertiary Formation is a series of sand layers encountered between the depths of 2,000' TVD and 4,500' TVD (see Attachment III). These sands are part of a northeasterly prograding complex of coastal plain and deltaic sediments of late Cretaceous to early Tertiary age. They are areally extensive and underlie the adj acent Kuparuk River and Prudhoe Bay Units on the North Slope of Alaska. Informally named, in descending order, the A, B, C and D sands, the units consist of interbedded sands separated by, gravels, coal beds · and clay. The A and B sands are predominantly a very fine-medium grained sand with a high lignitic coal content. The C and D sands are predominantly fine to coarse grained and often contain very coarse grained quartz and chert pebble conglomerates. Coal is much less evident in these lower sands. The Tertiary water sands thicken northeastward across the Milne Point Unit (see~ Attachment IV) and range in thickness from 400 feet in the southwest to 500 feet in the northeast. Structural dip is northeast at less than 20. Depth to the top of the A sand ranges from 2,000 feet (subsea) in the southwest part of the unit to 3,500 feet (subsea) in the northeast (see Attachment V). Note that the base of permafrost ranges from 1,500 feet subsea to 2,000 feet subsea at Milne Point and would begin to intersect the water sands along the western margin of the unit. Due to the permafrost conditions surface recharge of the Tertiary water sands at Milne Point is unlikely. Economics Total expenditures for the Central Facilities Pad water source well were $2.6 million. The Reverse Osmosis unit, necessary for conditioning the water, cost over $100,000 to purchase and install. The holding tank necessary for separation of the hydrocarbon gases and the waste water handling system required for disposing of the reject water, though part of the Unit's hydrocarbon processing system, cost Conoco in excess of $5,000,000. If the water source wells had not been necessary for enhanced recovery, potable water would have been obtained from surface sources more economically. Based on field experience, Conoco believes that the magnitude of the required initial investment satisfies the criterion for a Fresh Water Exemption as per State Regulations 20 AAC 25.440(a)(1)(B) and (C). Tertiary Water Sands Water Quality The TDS (Total Dissolved Solids) content of the Tertiary water within the Milne Point Unit is commonly 3000 to 4000 mg/L, which is within the limits established by the State of Alaska for fresh water (less than 10,000 PPM). The primary contaminants in the water, however, are chlorides. The insitu chloride concentration of the water is approxi- mately 1950 ppm which is 7.8 times the maximum limit established for potable water by the State. In addition, the water contains associ- ated hydrocarbon gas which must also be removed before it can be utilized as potable water. A storage tank is used to break-out the hydrocarbon gases, while a Reverse Osmosis unit is necessary to remove the chlorides and other dissolved solids. Downstream of the Reverse Osmosis system an activated charcoal filter removes trace amounts of purgable aromatics and other organic compounds. This system has been effective but the initial investment was very significant and maintenance costs have been much higher than antic- ipated. Listed below is a table of the dissolved solids from a water analysis of the Milne Point B-1 source well (refer to Attachments V(a), (b) and (c)). DISSOLVED SOLIDS CONCENTRATION (mg/1*) Calcium ................................. 135 Magnesium ............................... 20 Potassium ............................... 10 Bicarbonate ............................. (NA) Sulfate ...........................less than 1 Chloride ................................ 2000 Sodium .................................. 970 S i 0 2 .................................... (NA) Total Dissolved Solids 3300 *TDS number above includes only cations and anions for listed solids. Actual TDS number would be higher. Adjacent Operation Geological analysis indicates that the Tertiary Sands present in the Milne Point Unit are common to the adjacent Kuparuk River Unit. ARCO has been inj ecting contaminants into these Tertiary sands, wi thin their Kuparuk Unit, for several years. Though existing faults may prevent contaminants injected in the Kuparuk Unit from migrating to Milne Point, the possibility of contamination from the Kuparuk Unit would preclude any extensive development of the formation as a potable water source. The water produced from the Tertiary formation at Milne Point, with a chlorides content of approximately 2000 mg/1, is unfit for use as potable water. The process utilized by Conoco to reduce the chlorides of the produced water should not govern the classification of the formation as this type of system can also be used to process common sea water. Recovery of water from the Milne Point Tertiary water sands for the sole purpose of providing drinking water is economically impractical. Based on the points summarized above, Conoco believes that an aquifer ': C E.;i 1:-:;1., ......1:.', A(é~:,:~a 0;; exemption should be granted for the Milne Point Unit Shallow Sands (Tertiary and Upper Cretaceous). DGR/vv .....) 1,\::.,I...·.'~,rn~ U:. f (_1 ill C) --:.: {-~_. j r~2 g - ,~. SIMPSON L A G o 0 N ~ ',.,2'; "). .,) ~_ u:. ~~ ð 0 ~ MIL NE POINT :.~ r/j ~.)I~ ~ ~ .I'~h')' ~)I?"~' ~)I ~f"~'';! ~?"~, '~!Y/ /', ~ ~/. --. : @: : 0: ...... 1 I I 1 ."- 6 I 5 1 4 1 3 1 2 1 I I I 1 I 1 1 1 I I - - - _ _ _ _ _ oJ _ _ _ _ _ _ _ _ _ _ _1_ _ _ _ . __ I I 1 I KAVEARAK POINT ,-.-) c-> -.. C'1 f? ..,~ ~- I .·.1 r:·~ "- ~. "- . . ~ "'7": L 8 "- ..... \ ~. \C//////./;;//////-" """" C" [ @ <///.////////~ TI.~ ," 18 t7 "": 16 15 16~ 15 ~ -:; KUPARUK RIVER J: ~ " PARTICIPATING ...........-.. ~ ~ AREA BOUNDARY: ~ "- . "- "- 23 24 19 20 21 22. . . 24 21 22 "- ~ . ~ "- . "- )////////t/////////~ MILNE POINT : ~ ~/////////l////////> ~ UNIT BOUNDARY ~ "- "- "- "- "- 30. 29 28 27 26 "- ~ N ~ "- "- "- "- -V ." "- "- , "- "- "- , "- ~ 31 32 33 34 35 136 31 32 ~ "- "- Y////////l/////////r/////////~/////////(/////////~// ///</////////</////////~ 1\ 12 ~ -. 26 25 28 27 N --' 36 33 ~ð wUJ <>9 6 5 4 " /, E a: a: @) TRACT NO. S 2 3 4 5 , 1 I seA L E IN H I L E S Ww T 13 N T 12 N 3 2 Q= 6 5 a: a: > ~ ~ > o :I: ~ m z ~ CO NO CO MILNE POINT UNIT P ARTICIP A TING AREA BOUNDARY F E B R U A R Y 2 0, 1 9 8 7 SHE E T 0 F GR SP ....,;¡f.~~., ~ç ~~ ~~ . :..::;- ::.:š: <~ .....-:""" - ,·2.s r;. -..~""::" .~~ - [:;: ~ ~- ,.... .... -"... . .> - <~ .....~ "'- > ....:~ f'~ 1- ~ .~..' ;:::... ...~ - .¿~ " ?" :, ~ \.-::~~ - "'-'-4~ - '> ( ~ ,,;.' ~~ .~~-=- ~ '-. ~-...:::---""'::IIf' (~- -ç - ~~:~=... ~~ - ~ ~~~~ = ~f:':'-'; ~'......., ;¡- '. -=- I ~..::;~' ~ -.;c--:, ~. ~ " " ~) - ...-'l . ~ " <g.., ~ \ - ~. c:. '. ~ :. ,-,'> ..... - ~..:' ~~. S") ~ " ~': -- .~ -So " .... . '-- . - , ~~ Sources: Werner RES ::;a. ....!::~ f -.Þ ..;. ~-A ~ ~ - ,,-s- B C. __ _ '> ~:-- c ~ - c:.._ D ~-~ A -:... - ~ ';!oo B l ~ ~ A ~- ......::::=- .-- "-;- B ..- '$ ~ - ...... ~ ) ..J :- c "l=- ~ -:;; ~ A -£... - ~ - B ~ - -¡- =- ~ ~ '-º-- / ~ E -- ? ==- "S- --- ,:--~ A 1 ~ - """3 ;;-~ B "> ~ - ~ ~ ~ ~ - ...::- ,) ~- ;- E ~ ; ?- ( (984) J Chevron Un pub o SANDS M SAN OS L SANDS K SANDS N SANDS Re por t Cit en ::> o w u <{ I- W 0:: U - c:: C +- .s:::. u ~ +- U) Q) C ~ - - Q) c:: Q) u o Q) c CL - >- 0:: <{ I- 0:: W I- ? e8 --- c:: C +- ~ Q) u c:: ::> --- - .s:::. (,) ~ +- U) Q) C ~ - en ::> o w u <{ I- W 0:: U Unpub >- 0:: <{ I- 0:: W I- - Q) c:: Q) (,) o Q) c CL - Report en ::> o w u <{ I- W 0:: U - c:: C +- .s:::. (,) ~ +- U) Q) C :E o +- c:: C c C Q. E c u - - .s:::. (,) ... +- U) Q) C :E - en ::> o w u <{ I- W a:: U >- 0:: « .... 0:: W .... - Q) c Q) (,) o Q) c CL - ß Alaska. Oil 3~ G lS Cons. Comrnissïon TERMINOLOGY Afctrwít1:NE POI NT UN IT A- nforma I 0 0 a::: M ne pt. Unit <t: z o a::: > I.LJ ::t: o CJ) I.LJ I- o '0 CD -; :J CD a. g:~ ::J CJ) AGE 'i';·'~ , \~~q1:l.1 :c a,~ :\'- f ,I. DETERMINATIONS SHALLOW ) 01 L SANDS AGE ,~ I ) ATTACHMENT I - - - ~ ..... -4 >- o :x: ~ m z -4 T -------- 13 H MILNE POINT UNIT BASE MAP "1\._1 POI'" u..f (COt'IOCo) J -~ J MAP STRUCTURE I " IIT---J- ------------- ~-- II J I~ r I ~ - ----- ~ \ (þ \ 0 J~ n 0 JI 0 ---- ~- I '2 \ (j) ð' ;;-----;--0-- o 21 - ~.-r-- I I I u < __ __ I ..--~ I I .- U n -', U n·1O ""f 17 .. :". r --.... ---- -- _..-: ---=:..::....:_-- ,,. at ; , ~ , ' . I - ------ ----....~ ------- ..---.-----. . ----- II ., It ~ J' f I ¡ la )6 .. U I I I . i I \ ... (J'\¡ 0 0 " \ ;-----.- I'''~·~ 11 C ] :. I\.' . I. I ~~- ,~ . . /. . " j \~\ ~~~r·::\~ ., I I · · I. ~. _1 i CFP · ¡IIL-iu (\ I I Y; · 'u ~ ~.. I I Il Jl II I u ----- ...-- -- Ja ,. ,TOP OF "A" SA-ND .. \ ~ -- ---- 0-- . ~ø --- '0 o \~- '" .0 f j ~ .: - ~ . _ J _ _ "r:. ____ .,~ - ~ f-; II " j1-, III I I i I I /21 21 I I í ! . JJ I~ ,;.~~~. rtI v- II II II ----- ---- - -~~-- .. It I NO.TWW.." .'''He . I " II r ¡.-:;---- I "'t r¡~;------ñ------lrñ-------N H " 10 f .' .. ~, t~ :¡; J.. ft-- I," :1: ,; ~2 " . r . :J .":) ,) [ ) -, ',' (;) ~¡t t .!.: r .. (j) ~~~~ Ç?:I . - ï.---·~J·-~·-- ~ 9 ...!--~ fj ~1- f;J ,.. II n II II .1 ,s N It I' \~- I - 10 I' , ~ '.. n-n , ' .. --.-- u , r- ß- » -I -I » 0 (conoco) ::I: W.l". POI.I UII,r 3: MilNE POINT UNIT m Z BASE MAP -I < 1 J -t 1.- .. .1 ----------------- a, T 113 H In _/-~!~ -~ ----------------------------~ .0 II U " ._-.. ... I H (;.---. ~ r -- ------ -- n - - 111 I"'·' I "II[ 11 ,<I: t. r ~, ¡:, '. TERTIARY WATER··SAND-S.JSOPACH MAP 1__ " II [ I -r ¡'rr i 11 ----¡ i. ~ . I I I - .__ I ~_____ ...____ I I" ---t---- I : II -----: ,ï'-------ïi- -- -- , ..-- --- ~ I I r I ~~~~~ \ I- n_ ~\ C I I 6' ., f¿: : 0\ ( \ ' .' . I .1, I . /0,- \ _ "'. : ¡;; c.~:i - ------.. - \ Ar·D~,...J~7 ';-~ · t - · .-\~ - 'l // l~ - A.1 · ~";!···i· i CFP · .' . I 121 . \' ". . I i L: '\ ).... ,.'¡.. .t:~... ¡ \ I ,.... !U i I 10 Ia II It 1I 10 n 2. r- r., (-) ~ : tj II 10 I .- <.. --,J " . f , . . ,-"1. ,_ J ij :J i;!d CJ :~ :'7" j~' f, , . ~o (-; . - ·¡¡;~:·-·:¡tl .~.) r) c-; ~:) II ç-_J .. ., .. ----------- F0 ~'~. h.~t -r... 10 21 V 2' U N 6' I I q 0...1 I Î I, Ia A .... II~ " n· ,.. II " n f ) ll. II IS' II III II .1 iL,', .0 ! ,. . I I ,., .s .1 ~._- . , -_._~. to ~ I ,\~. .,.. . 10 I I:"" I .. II II II .. II II I~ ,- --- --- -- - --..._--- ~_._. IIIIO.'MW.." ...n.... . I ...------- Mill 1I II 10 [ 11'[ --r¡~~------~--------"------~. Ie , , ) ATTACHMENT V (a) ) 21:54 SAMPLE lOCAIJON ~i1 ne Point. ~ RECVD. BY.. . ET,Y ..lAB :# 4601 OATERECVD. 10/21/8,6. DA TE COMPLETED 1 O/,2~J86 Of.. TE REPORTED 10/27/86 SIGHATURF .~ 4601 ~D H~DIC^TES · lOl~E DETfCTED' ~~~~~_~___ __________ nA TE- 10/28/85 ___. _ DETECTIOH LIMIT IS IH ( ) ; ----------~-~--------~~=============~~~~~~===~===========~~==========~=== . . CUSTOMER. Conoea. Inc. _ Milne Pnint IInit DATE COLlECTED 10/20/86 TInE COLLECTED 1500 SMíPlED BY C. S. SOURCE B-1 Source Water We 11 B-1 F 1 owltn.e.._ REMARKS HA rRIX m,g/1 mg/1 mg/1 )ALUMINUM, AI ND (n.ns) ) STRONTIUM. Sr 2.5. ) TOTAL DISSOLVED 3300 SOUDS ) ARSENIC. As NO (0.05) ( ) T!N, Sn.. .. -- NO (0.05) ) TOTAL VOLATILE SOLIDS ) BARIUM. Sa 6.1 ( ) V AN.o\DIUM. V ND (0.05) ) SUSPENDED .. SOl.IDS ) BORON, B o ~ on ) ZINC. Zn 0.051 ) VOLATILE SUSPENDED N~_ ~O.05) , SOLIDS ) CALCIUM. C3 - 135 ) ZIRCONIUM, Zr__ ) HARDNESS AS 420 ND (0.002) CaCOJ 122 ) CAD\'IIUM. Cd .. ~. ( )- ) AL~AL.1NIT'f AS NO (0.05) CaCO) ) CHROMIUM. Cr ) ) COPPER, Cu NO (b.oS) ) .- - ) IRON, Fe -. 0.82 ) AMr-.10NIA - NITkOOEN·N ) LEAD, Pb ND (9.05) ( ) IOELDAHL " , NJTROGEN·N ) f\ IAGNESJUM. Mg 20 ( ) N1TRA TE-N ) f\JANOANESE. Mn 0.21 ) NITRJTE-N ) MERCURY. Hg ~ND (0.05) ) CHlOR,IDE ) NICr::eL. NI~ NO (0.05) ) CY ANJDE ) PHOSPHOROUS. P - 0.011 ) FLUORIDE: _ ) POT^SSJU~'. K . .lQ ) ÖIL AND GREASE ( ) .sElE:--:fU~1. Sc NO (0.05) ) PHE~OL ) Sf LlCO~. Si 6.2 ) PHOSPHOROUS .- NO (0.05) . (ORTHO}.P ) SIt. VER. Ag. ) SULfATE_ 970 ( ) SULFIDE CH;S) ) SODIU~t. ~:s - ***********~*********** ) COI..OR·UNfTS ) CO:-':DUCTIYJT'f. .. 7000 umho.s/cm 2-,-000 _ (') LANCLJER INDEX' ) ~ANCiLJ1:'R INDE.X ,( ) pH, UNITS _ 7.9 ) TliRUIDITY. nlU. c ),,' èOLrFOR~f/JOOmJ c ). - ND (1) ( ). :'\ ',__ _. . J'._ -..., f'.\ ...., ¡,r":"'I¡'L.~_¡_\'::"~. I...i~~ '...:,. (.~.J , . . . '-'. ¡.; ,-,...... -......" c: (.. 2~~ ,"",.~- .,.. "-" (-', .1 G ,.Iltl 1111 1111 1111 IUl 1111.1111 1111. III! 11\1 CO¡ LOGARITHMIC No T~III .1111111 IIlIìlll ,.jill/II I I "rill I III"" 1111"11 I 1!'fIIII Ci C. 1::\tI i IlIljlll ¡'''1111 411::" I' ill"11 IIII'H' '"11111 · "1"11 MCO¡ 1169 "~lIi IIII!" 1 '4111!" I ."'I"-i .III~III IlIrlll t n1I14 I "~IM so. , 111,111 I 11111u t "11111 I 1I1!11\ I I 1I11I1l IIIIIII! I It"''' III"'" eo, § ~ § 2 - ~ ~ ~ ~ c. 1111 H II 1111 Ii II III i : Ii! lIB \I '.I III t III t, HOO¡ 1tt·IIH 1HIIIIIIHIIIII"¡HI :111 HII iilH\ll~ WATER PATTERNS-TMll STANÞAftD Na II~II¡ 11,\'°1111 111,°11''11 ,",'°1111 ,,,~oldl ca. _ 7. f\, :....J....Q.'lL- OTHER PR01'ERT1ES ~~6C: Gravit~, $0/60 F. Reliltivity (ohm ·tQtter5 )--F. ANALYSIS RESULTS Date Samplèd: 12-25-86 Analysis By: JHal ,. "11 J III. lIlt II \.J I t II "" JIll "" II I! !III CO¡ LO<JARITHWIC tI, II~II Wil'I I '''"lI' <11I111 I 1111'"1 1111"11 1 "1"11 11111111 C1 C. III~II ¡ ..llill I .,11:111 ."~tll IlIr"1 I Urlll . .11111: '1411"1/ "COa iii, "~tll III'III ~:1~" I .III" LHI ~III III~II ¡Ur"' III~II¡ ~ "f'" 'fl" 'f'" '2""" ';.. ''''''k' "~'i!' "'''I' "'''r'' c. 1111 fill :III HII :111'1111 HII III1 IIi! HHHOOa MV I I II 1111 II H 1111 ! HI 1111 II H I HI 1\ It 11 II so.. WATER PATTERNS-me/l STANþAftÞ to 10 0 10 20 filII III-¡ III ¡- 1111 III' III I I ¡1 I I HI 1111 II II II J' C1 7.~¡ L rj ò ö ~ ~ ¡a 0 OTHER PROPERTIES ~~~e Gravity, SO/60 F. RCs.iativity (ohmolIle!t.en)--F. RE~KS " RECOMMENDATIONS: i.)~5 Iron, Fe (total) ~cie, .. BaS Tot&1 Dl..o\....d SoUd. (ca1~~ 160 7~trl Anionq 1955 50,8 º.l (/ L, 1800 4 .l)~- ANIONS Chloride, C1 Sulfate, SO. Cubonat6. CO. Blcarbonat4, Bco. 'fMll 4]_;. 6.9 n.C) 1].1 1tIg/1 1~1g 11 10 '1205'" DISSOLVED SOLIDS CATIONS Sodiur.c, N & (calc..) C.lc.iUXIl, Ca }!a~esiwu, M¡ Banum, Sa !ot$.l èations Sample Point: Plowli~e Sample LD.: R-l RE1LARXS A RECOMMENDATIONS: 0.7 hon, F. (t.otaJ) ~dc, u fuS 'rota] DluolY'ed SoUd. (calc.) 1'S19 DISSOLVED SOL1DS CATIONS trlg/l me/I Sodium. Na (calc..) 11 g4 51.9 Calcium, Ca lJQ ~.~ MafDU)UJn, M¡ D IJ.:; Barium. Ba ' , I). :2 T~!:n.l c..lt~ 0r,R 1.. 'f .............. ANIONS Chlorid., C1 195Q 5ð:~ &ill.toe. so. zJ Ca.tbonate.. C(h . ù Bicarbona tA, Bco. .. . () 1'o_taJ. A..'1icns -m¡- Hal Stevens Analysis By: ANALYSIS RESULTS )- 9/25/86 Date Sampled: WATER ANALYSIS REPORT 'Stiù;pi.e, I .D.: B-1 ATTACHMENT V (b) ') ~, Sample Point: Flc'Wli:1e ') OJ 2~=::=:i 2'~: 5~ fl!U:E F'CIUiT D.C. A TT ACHMENT V (c) )' t ID. 011 ~.::o:=' --- CHEMICAL & G1~LOGICAL LABORATORIES ,~.,' . / /6/~~ ~, ~ 1 .- TELEPHONE (907) 562·2343 ANCHORAGE INDUSTRIAL CEN ~633 8 SCreel ANALYTICAL REPORT CUSTOMER Conoco, Inc. SAMPLE LOCATION: DATe COLLECTED 1-5-86 TIME COLLECTED: __1300 SAMPLED BY Hal Stevens SOURCE CFP #l-Raw Water REMARKS ~are.lY hard, Alkaliné water with ~gh Ir.on, Manqanss8, ScxUum, Chl9;-jde and Total Di.ssol....ed Sol id~. mg/1 )ALUMINUM, AI <0.05 ) ARSENIC, As <0.001 ) BARIUM. Sa 5.4 ) BORON, B ) CAL.CIUM. Ca 105 ) CADMIUM. Cd <0.01 ( ) CHROMIUM, Cr <0.05 ) COPPER. Cu <0.05 ) IRON. Fe 0.62 ) LEAD. Pb <0.05 ) MAGNESIUM, M¡ 17 ) MANGANESE, Mn 0.14 ) MERCURY. Hi <0.0002 ) NICKEL. NI ) PHOSPHOROUS. P 0.21 ) POTASSIUM, K 11 ) SELENIUM, Se <0.001 ( ) SILICON, Si 5.0 ) SILVER, Ag <0.05 ( ) SODIUM. Na ala øs ~Oð mg/1 ) STRONTIUM. Sr ) TIN. Sri ) VANADIUM, V ) ZINC, Zn <0.05 ) ZIRCONIUM, Zr )_. -- ) AMMONIA . NITROGEN·N ) KJELDAHL NITROGEN·N ) NITRA TE·N <0.10 ) NITRITE·N _ } CHLORIDE ) CYANIDE ) FLUORIDE ) OIL. AND GREASE 0.69 ) PHENOL ) PHOSPHOROUS (ORTHO)-P ( )SULFATE 0.11 ) SULFIDE (HIS) Milne Point FOR LAB USE ONLY RECVD. BY DB LAB ~ 1690 DA TE RECEIVED 1-6-86 DATE COMPLETE01-10-86 DATE REPORTe:O 1-17-86 SIGNED_;r,"¡i(~, t\.. (/. £12 ~ mg/1 ) TOTAL DISSOLVED SOLIDS ) TOTAL VOLATILE SOLIDS ) SUSPENDED SOLIDS ) VOLATILE SUSPENDED SOLIDS ) HARDNESS AS CaC03 ) ALKALINITY AS CaCO) ) 2500 332 110 ) , ***********.************ ) COLOR-UNITS 1500 ) CONDUCTIVITY, umhos/em ) LANGLIER INDEX 4200 ) LANGLlER INDEX ) pH. UNITS '.8 ) TURBIDITY, ntu COLIFORM/1OOml ( ) ". ...... It ¡J?, r" ,........ ...."