Cypress Environmental Partners (CELPQ) 8-K 8 Jun 15 2014 FY Financial Statements and Supplementary Data Financial data

Document_And_Entity_Informatio

Document And Entity Information (USD $)	12 Months Ended
	Dec. 31, 2014	Jun. 30, 2014	Mar. 25, 2015
Document Information [Line Items]
Entity Registrant Name	Cypress Energy Partners, L.P.
Document Type	8-K
Current Fiscal Year End Date	-19
Entity Public Float		$102,594,375
Amendment Flag	FALSE
Entity Central Index Key	1587246
Entity Current Reporting Status	Yes
Entity Voluntary Filers	No
Entity Filer Category	Non-accelerated Filer
Entity Well-known Seasoned Issuer	No
Document Period End Date	31-Dec-14
Document Fiscal Year Focus	2014
Document Fiscal Period Focus	FY
Subordinated Units [Member]
Document Information [Line Items]
Entity Common Stock, Shares Outstanding			5,913,000
Common Units [Member]
Document Information [Line Items]
Entity Common Stock, Shares Outstanding			5,913,000

Consolidated_Balance_Sheets

Consolidated Balance Sheets (USD $)	Dec. 31, 2014	Dec. 31, 2013
In Thousands, unless otherwise specified
Current assets:
Cash and cash equivalents	$20,757	$26,690	[1]
Trade accounts receivable, net	54,075	60,730	[1]
Deferred tax assets	68	134	[1]
Deferred offering costs	0	2,539	[1]
Prepaid expenses and other	2,440	1,458	[1]
Total current assets	77,340	91,551	[1]
Property and equipment:
Property and equipment, at cost	27,878	42,529	[1]
Less: Accumulated depreciation	3,538	3,711	[1]
Total property and equipment, net	24,340	38,818	[1]
Intangible assets, net	30,245	32,551	[1]
Goodwill	55,545	75,466	[1]
Debt issuance costs, net	2,318	2,149	[1]
Other assets	54	55	[1]
Total assets	189,842	240,590	[1]
Current liabilities:
Accounts payable	2,461	2,673	[1]
Accounts payable - affiliates	586	0	[1]
Accrued payroll and other	7,750	10,662	[1]
Income taxes payable	546	16,158	[1]
Total current liabilities	11,343	29,493	[1]
Long-term debt	77,600	75,000	[1]
Deferred tax liabilities	438	541	[1]
Asset retirement obligations	33	9	[1]
Total liabilities	89,414	105,043	[1]
Commitments and contingencies - Note 10	0		[1]
Parent net investment attributable to controlling interests	0	130,012	[1]
Parent net investment attributable to non-controlling interests	0	719	[1]
Partners’ capital:
General partner	1,999	4,816	[1]
Accumulated other comprehensive loss	-525	0	[1]
Total partners' capital	73,855	4,816	[1]
Non-controlling interests	26,573	0	[1]
Total parent net investment and owners' equity	100,428	135,547	[1]
Total liabilities, parent net investment and owners' equity	189,842	240,590	[1]
Common Units [Member]
Partners’ capital:
Limited partner	6,285	0	[1]
Subordinated Units [Member]
Partners’ capital:
Limited partner	$66,096	$0	[1]
[1]	Recast - Note 2

Consolidated_Balance_Sheets_Pa

Consolidated Balance Sheets (Parentheticals)	Dec. 31, 2014
Common Units [Member]
Limited partner, units outstanding	5,913,000
Subordinated Units [Member]
Limited partner, units outstanding	5,913,000

Consolidated_Statements_of_Ope

Consolidated Statements of Operations (USD $)	12 Months Ended
In Thousands, except Share data, unless otherwise specified	Dec. 31, 2014	Dec. 31, 2012
Revenues	$404,418	$619
Costs of services	355,355	309
Gross margin	49,063	310
Operating costs and expense:
General and administrative	21,321	2,056
Depreciation, amortization and accretion	6,345
Impairments	32,546
Operating (loss) income	-11,149	-1,845
Other income (expense):
Interest expense, net	-3,208
Offering costs	-446
Gain on reversal of contingent consideration	0
Other, net	92
Net (loss) income before income tax expense	-14,711
Income tax expense	468	0
Net (loss) income	-15,179	-1,845
Net income attributable to non-controlling interests	4,973
Net (loss) income attributable to partners / controlling interests	-20,152
Net income attributable to general partner	149
Net Income	-20,301
Net loss per common limited partner unit – basic and diluted (in Dollars per share)	($1.72)
Weighted average common units outstanding - basic and diluted (in Shares)	5,913,000
Weighted average subordinated units outstanding - basic and diluted (in Shares)	5,913,000
Predecessor [Member]
Revenues		12,203
Costs of services		3,662
Gross margin		8,541
Operating costs and expense:
General and administrative		477
Depreciation, amortization and accretion		1,398
Impairments		0
Operating (loss) income		6,666
Other income (expense):
Interest expense, net		-111
Gain on reversal of contingent consideration		0
Other, net		40
Net (loss) income before income tax expense		6,595
Income tax expense		0
Net (loss) income		6,595
Common Units [Member]
Other income (expense):
Net Income	-10,150
Subordinated Units [Member]
Other income (expense):
Net Income	($10,151)
Net loss per subordinated limited partner unit – basic and diluted (in Dollars per share)	($1.72)

Consolidated_Statements_of_Com

Consolidated Statements of Comprehensive Income (Loss) (USD $)	12 Months Ended
In Thousands, unless otherwise specified	Dec. 31, 2012
Net (loss) income	($1,845)
Predecessor [Member]
Net (loss) income	6,595
Other comprehensive income (loss) –foreign currency translation	0
Comprehensive (loss) income	6,595
Comprehensive income attributable to non-controlling interests	0
Comprehensive (loss) income attributable to partners/controlling interests	$6,595

Consolidated_Statement_of_Owne

Consolidated Statement of Owners' Equity (USD $)		Predecessor [Member]	Parent Net Investment Attributable to Controlling Interest [Member]	Parent Net Investment Attributable to Non Controlling Interest [Member]	General Partner [Member]	Common Units [Member]	Subordinated Units [Member]	AOCI Attributable to Parent [Member]	Noncontrolling Interest [Member]	Owners Equity [Member]	Total
In Thousands
Balance at Dec. 31, 2011		$9,265	$0	$0	$0	$0	$0	$0	$0	$0
Contributions		2	1	0	0	0	0	0	0	0
Net advances from (distributions to) members		8,907	-505	0	0	0	0	0	0	0
Net income (loss)		6,595	-1,845	0	0	0	0	0	0	0	-1,845
Foreign currency translation adjustment		0
Purchase of Predecessor entity		-24,769	24,769	0	0	0	0	0	0	0
Member contributions in excess of Predecessor equity (Recast - Note 2)	[1]	0	44,077	0	0	0	0	0	0	0
Balance at Dec. 31, 2012	[1]	0	66,497	0	0	0	0	0	0	0
Contributions			0	0	6,210	0	0	0	0	6,210	6,200
Sale of member interest in subsidiary			0	697	0	0	0	0	0	0
Net advances from (distributions to) members			-5,763	0	0	0	0	0	0	0
Parent investment in TIR Entities			63,617	0	0	0	0	0	0	0
Purchase of non-controlling interests			-572	0	0	0	0	0	0	0
Stock option expense			90	0	0	0	0	0	0	0
Tax benefit of stock options exercised over FMV			528	0	0	0	0	0	0	0
Net income (loss)			5,727	22	-1,394	0	0	0	0	-1,394	4,355	[1]
Foreign currency translation adjustment			-112	0	0	0	0	0	0	0	-112	[1]
Balance at Dec. 31, 2013	[1]		130,012	719	4,816	0	0	0	0	4,816	135,547
Net income (loss)			1,092	-6	-446	0	0	0	0	-446
Foreign currency translation adjustment			-304	0	0	0	0	0	0	0
Balance at Jan. 20, 2014
Balance at Dec. 31, 2013	[1]		130,012	719	4,816	0	0	0	0	4,816	135,547
Contributions				0	979	0	0	0	0	979	500
Contribution of Predecessor and 50.1% of TIR Entities in exchange for units			-130,632	-713	0	22,491	82,470	-208	26,592	131,345
Proceeds from initial public offering, net of offering costs			0	0	-2,853	80,213	0	0	0	77,360
Distribution of initial public offering proceeds to Cypress Energy Holdings, LLC			0	0	0	-80,213	0	0	0	-80,213
Distributions to partners			0	0	0	-6,532	-6,532	0	0	-13,064
Distributions to non-controlling interests			0	0	0	0	0	0	-4,683	-4,683
Net advances from (distributions to) members			-168	0	0	0	0	0	0	0
Stock option expense			0	0	0	476	309	0	0	785
Net income (loss)											-15,179
Foreign currency translation adjustment											-937
Balance at Dec. 31, 2014			0	0	1,999	6,285	66,096	-525	26,573	100,428	100,428
Balance at Jan. 20, 2014
Net income (loss)			0	0	-497	-10,150	-10,151	0	4,979	-15,819
Foreign currency translation adjustment			0	0	0	0	0	-317	-315	-632
Balance at Dec. 31, 2014			$0	$0	$1,999	$6,285	$66,096	($525)	$26,573	$100,428
[1]	Recast - Note 2

Consolidated_Statement_of_Owne1

Consolidated Statement of Owners' Equity (Parentheticals) (Owners Equity [Member])	12 Months Ended
	Dec. 31, 2014
Owners Equity [Member]
Percentage of ownership interest conveyed	50.10%

Consolidated_Statements_of_Cas

Consolidated Statements of Cash Flows (USD $)	10 Months Ended		12 Months Ended
In Thousands, unless otherwise specified	Dec. 31, 2012		Dec. 31, 2012
Operating activities:
Net income (loss)	($1,845)	[1]	($1,845)
Adjustments to reconcile net income (loss) to net cash provided by (used in) operating activities:
Depreciation, amortization and accretion	99	[1]
Impairments	0	[1]
Loss on asset disposal	0	[1]
Gain on reversal of contingent consideration	0	[1]
Interest expense from debt issuance cost amortization	0	[1]
Amortization of equity-based compensation	0	[1]
Equity earnings in investee company	0	[1]
Distributions from investee company	0	[1]
Deferred tax benefit, net	0	[1]
Non-cash allocated expenses	0	[1]
Changes in assets and liabilities:
Trade accounts receivable	-741	[1]
Prepaid expenses and other	-12	[1]
Accounts payable and accrued payroll and other	255	[1]
Income taxes payable	0	[1]
Net cash provided by (used in) operating activities	-2,244	[1]
Investing activities:
Cash acquired (see Note 4)	0	[1]
Acquisitions of businesses	-65,555	[1]
Purchases of property and equipment	-58	[1]
Net cash provided by (used in) investing activities	-65,613	[1]
Financing activities:
Proceeds from initial public offering	0	[1]
Distribution of initial public offering proceeds (see Note 3)	0	[1]
Payment of offering costs	0	[1]
Proceeds from long-term debt	0	[1]
Repayment of long-term debt	0	[1]
Payment of debt issuance costs	0	[1]
Payments on behalf of affiliates	-505	[1]
Purchase of non-controlling interests	0	[1]
Tax benefit of stock options exercised	0	[1]
Net contributions from (distributions to) members prior to IPO	68,846	[1]
Contributions from general partner	0	[1]
Distributions to limited partners	0	[1]
Distributions to non-controlling members of the TIR Entities	0	[1]
Net cash provided by (used in) financing activities	68,341	[1]
Effect of exchange rates on cash	0	[1]
Net increase (decrease) in cash and cash equivalents	484	[1]
Cash and cash equivalents, beginning of period	0	[1]
Cash and cash equivalents, end of period	484	[1]	484	[1]
Non-cash items:
Accounts payable excluded from capital expenditures	145	[1]
Supplemental cash flow disclosures:
Cash taxes paid	0	[1]
Cash interest paid	0	[1]
Predecessor [Member]
Operating activities:
Net income (loss)			6,595
Adjustments to reconcile net income (loss) to net cash provided by (used in) operating activities:
Depreciation, amortization and accretion			1,398
Impairments			0
Loss on asset disposal			0
Gain on reversal of contingent consideration			0
Interest expense from debt issuance cost amortization			0
Amortization of equity-based compensation			0
Equity earnings in investee company			0
Distributions from investee company			0
Deferred tax benefit, net			0
Non-cash allocated expenses			0
Changes in assets and liabilities:
Trade accounts receivable			-219
Prepaid expenses and other			-353
Accounts payable and accrued payroll and other			-175
Income taxes payable			0
Net cash provided by (used in) operating activities			7,246
Investing activities:
Cash acquired (see Note 4)			0
Acquisitions of businesses			0
Purchases of property and equipment			-15,236
Net cash provided by (used in) investing activities			-15,236
Financing activities:
Proceeds from initial public offering			0
Distribution of initial public offering proceeds (see Note 3)			0
Payment of offering costs			0
Proceeds from long-term debt			0
Repayment of long-term debt			-484
Payment of debt issuance costs			0
Payments on behalf of affiliates			0
Purchase of non-controlling interests			0
Tax benefit of stock options exercised			0
Net contributions from (distributions to) members prior to IPO			8,909
Contributions from general partner			0
Distributions to limited partners			0
Distributions to non-controlling members of the TIR Entities			0
Net cash provided by (used in) financing activities			8,425
Effect of exchange rates on cash			0
Net increase (decrease) in cash and cash equivalents			435
Cash and cash equivalents, beginning of period			147
Cash and cash equivalents, end of period	582		582
Non-cash items:
Accounts payable excluded from capital expenditures			91
Supplemental cash flow disclosures:
Cash taxes paid			0
Cash interest paid			$111
[1]	Recast - Note 2

Note_1_Organization_and_Operat

Note 1 - Organization and Operations	12 Months Ended
	Dec. 31, 2014
Disclosure Text Block [Abstract]
Organization, Consolidation and Presentation of Financial Statements Disclosure [Text Block]	1	Organization and Operations
	Cypress Energy Partners, L.P. (the “Partnership”) is a Delaware limited partnership formed on September 19, 2013 to provide saltwater disposal (“SWD”) and other water and environmental services to U.S. onshore oil and natural gas producers and trucking companies and to provide independent pipeline inspection and integrity services to producers and pipeline companies.  On January 21, 2014, we completed the initial public offering (“IPO”) of our common units representing limited partner interests.  In connection with the IPO, Cypress Energy Holdings II, LLC (“Holdings II”), a wholly owned subsidiary of Cypress Energy Holdings, LLC (“Holdings”), conveyed a 100% interest in Cypress Energy Partners, LLC (“CEP LLC”), in exchange for (a) an aggregate 47.8% interest in the Partnership comprised of 671,250 common units and 4,983,750 subordinated units, and (b) the right to receive the proceeds of the IPO.  Prior to its contribution to the Partnership, CEP LLC distributed to Holdings its interest in SBG Sheridan Facility, LLC, which owns and operates a SWD facility in Sheridan, Montana as well as its interest in three other non-operating subsidiaries.  In addition, affiliates of Holdings, conveyed an aggregate 50.1% interest in Tulsa Inspection Resources, LLC (“TIR LLC”), Tulsa Inspection Resources – Nondestructive Examination, LLC (“TIR-NDE”) and Tulsa Inspection Resources Holdings, LLC (“TIR Holdings”) (collectively, the “TIR Entities”) to the Partnership in exchange for an aggregate 15.7% ownership in the Partnership comprised of 929,250 common units and 929,250 subordinated units.  The Partnership subsequently conveyed its interest in the TIR Entities to CEP LLC.  Together, CEP LLC and the TIR Entities are hereafter collectively referred to as the “Contributed Entities”. Affiliates of Holdings held the remaining 49.9% interest in the TIR Entities not contributed to the Partnership until February 1, 2015 when the Partnership acquired the remaining interest (see Note 17).
	Our business is organized into the Water and Environmental Services (“W&ES”) and Pipeline Inspection and Integrity Services (“PI&IS”) reportable segments.  All remaining business activities are included in Other. W&ES provides services to oil and natural gas producers and trucking companies and consists of the operations of CEP LLC.  CEP LLC is a Delaware limited liability company, which was formed on March 15, 2012 (Inception) and acquired 100% of the outstanding units of seven North Dakota limited liability companies from SBG Energy Services, LLC (“SBG Energy”) on December 31, 2012.  Since the acquisition of these companies, the president and chief executive officer of SBG Energy has served as a member of our board of directors.  These seven companies collectively comprise our predecessor for accounting purposes (“Predecessor”).  These Predecessor entities were formed in 2011 and 2012, with the first being formed on June 1, 2011. CEP LLC currently owns and operates eight commercial SWD facilities in the Bakken Shale region of the Williston Basin in North Dakota, as well as two in the Permian Basin in Texas.  All of the facilities currently utilize specialized equipment, full-time attendants, and remote monitoring to minimize downtime and increase efficiency for peak utilization.  These facilities also contain oil skimming processes that remove any remaining oil from water delivered to the sites.  In addition to the SWD facilities, our consolidated 51% subsidiary, Cypress Energy Services, LLC (“CES LLC”), provides management and staffing services for three additional SWD facilities in the Bakken Shale region, pursuant to management agreements.  CES LLC also owns a 25% member interest in one of the managed facilities.  CES was acquired effective October 1, 2013.
	PI&IS provides inspection and integrity services to various energy, public utility and pipeline companies in both the United States and Canada and consists of the operations of the TIR Entities.  Our inspectors perform a variety of services on midstream pipelines, gathering systems and distribution systems, including data gathering and supervision of third-party construction, inspection, and maintenance and repair projects.  Services are provided in Canada through two wholly owned subsidiaries of TIR Holdings – Tulsa Inspection Resources-Canada, ULC (“TIR-Canada”) and Foley Inspection Services, ULC (“TIR-Foley”) – both Canadian unlimited liability corporations.
	Other includes other business activities that are not operating segments, as well as corporate operations.

Note_2_Basis_of_Presentation_a

Note 2 - Basis of Presentation and Significant Accounting Policies	12 Months Ended
	Dec. 31, 2014
Disclosure Text Block [Abstract]
Basis of Presentation and Significant Accounting Policies [Text Block]	2	Basis of Presentation and Significant Accounting Policies
	Basis of Presentation
	The financial information for periods prior to the IPO have been recast to reflect the conveyance of the Contributed Entities to the Partnership at the closing of our IPO, as if the contribution of CEP LLC had occurred as of March 15, 2012, the inception date of CEP LLC, and the contribution of the TIR Entities had occurred as of June 26, 2013, as Holdings and its affiliates did not acquire a controlling interest in the TIR Entities until June 26, 2013.  All significant intercompany transactions and account balances have been eliminated.  We have made certain reclassifications to the prior period financial statements to conform with classification methods used in the current fiscal year.  These reclassifications had no impact on previously reported amounts of total assets, total liabilities, owners’ equity, or net income.
	The information presented for our Predecessor for 2012 includes the activity of the four subsidiaries contributed to Holdings prior to the contribution of CEP LLC to the Partnership and does not reflect the fair value of the assets and liabilities recorded by the Partnership when the Predecessor was acquired by CEP LLC (see Note 4).
	The accompanying Consolidated Financial Statements have been prepared in accordance with accounting principles generally accepted in the United States (“GAAP”) for consolidated financial information and in accordance with the rules and regulations of the Securities and Exchange Commission.  The Consolidated Financial Statements include all adjustments considered necessary for a fair presentation of the financial position and results of operations for the periods presented.  Such adjustments consist only of normal recurring items, unless otherwise disclosed herein.
	Principles of Consolidation
	The Consolidated Financial Statements include the accounts of the Partnership.  All intercompany accounts and transactions have been eliminated in consolidation.
	Use of Estimates in the Preparation of Financial Statements
	The preparation of the Partnership’s Consolidated Financial Statements in conformity with GAAP requires management to make estimates and assumptions that affect the amounts reported in the Consolidated Financial Statements and accompanying notes.  Actual results could differ from those estimates.
	Areas requiring the use of assumptions, judgments, and estimates include amounts of expected future cash flows used in determining possible impairments of goodwill, intangible assets, property and equipment, the determination of fair values associated with the allocation of purchase price in business combinations, and future asset retirement obligations.  Certain estimates are inherently imprecise and may change as future information becomes available.  Judgments and assumptions used in the Partnership’s estimate of future cash flows and an asset’s fair value include such matters as the estimation of oil and gas drilling and producing volumes in the markets served, risks associated with the different geological formation zones into which salt water is disposed, expected future disposal rates and commodity prices, capital expenditures, operating costs and appropriate discount rates.  The use of alternative judgments and/or assumptions could result in different outcomes.
	Fair Value Measurement
	The Partnership utilizes fair value measurements to measure assets in a business combination or assess impairment of property and equipment, intangible assets and goodwill. Fair value is the amount received from the sale of an asset or the amount paid to transfer a liability in an orderly transaction between market participants (an exit price) at the measurement date. Fair value is a market-based measurement considered from the perspective of a market participant. The Partnership uses market data or assumptions that it believes market participants would use in pricing the asset or liability, including assumptions about risk and the risks inherent in the inputs to the valuation.  These inputs can be readily observable, market corroborated, or unobservable.  The Partnership applies both market and income approaches for fair value measurements using the best available information while utilizing valuation techniques that maximize the use of observable inputs and minimize the use of unobservable inputs.
	The fair value hierarchy prioritizes the inputs used to measure fair value, giving the highest priority to quoted prices in active markets for identical assets or liabilities (Level 1 measurement) and the lowest priority to unobservable inputs (Level 3 measurement).  The Partnership classifies fair value balances based on the observability of those inputs.  The three levels of the fair value hierarchy are as follows:
		•	Level 1 – Quoted prices for identical assets or liabilities in active markets that management has the ability to access.  Active markets are those in which transactions for the asset or liability occur in sufficient frequency and volume to provide pricing information on an ongoing basis.
		•	Level 2 – Inputs are other than quoted prices in active markets included in Level 1 that are either directly or indirectly observable.  These inputs are either directly observable in the marketplace or indirectly observable through corroboration with market data for substantially the full contractual term of the asset or liability being measured.
		•	Level 3 – Inputs that are not observable for which there is little, if any, market activity for the asset or liability being measured.  These inputs reflect management’s best estimate of the assumptions market participants would use in determining fair value.
	Contributions from General Partner
	During 2013, entities affiliated with Cypress Energy Partners, GP, LLC, (“General Partner”) incurred $6.2 million of costs associated with our initial public offering and our credit agreement.  These costs were transferred to the Partnership as offering costs, deferred offering costs and/or debt issuance costs and have been recorded as contributions to the Partnership.
	During 2014, Holdings incurred allocated overhead expenses on behalf of the Partnership totaling $0.5 million. These costs represent amounts incurred by Holdings in excess of amounts charged under our amended and restated omnibus agreement.  These expenses are reflected as general and administrative in the Consolidated Statement of Operations for the year ended December 31, 2014 and as an equity contribution in the Consolidated Statement of Owners’ Equity.
	Cash and Cash Equivalents
	The Partnership considers all investments purchased with initial maturities of three months or less to be cash equivalents.  Cash equivalents consist primarily of investments in highly liquid securities.  The carrying amounts of cash and cash equivalents reported in the balance sheet approximate fair value.
	U.S. cash balances at December 31, 2014, are insured by the Federal Deposit Insurance Corporation (FDIC) up to $250 thousand per financial institution.  Canadian cash balances are insured by the Canada Deposit Insurance Corporation (CDIC) up to $100 thousand per financial institution.  At times, cash balances may be in excess of the FDIC or CDIC insurance limits.  We periodically assess the financial condition of the institutions where we deposit funds and for the years ended December 31, 2014 and 2013, we believe our credit risk related to these funds is minimal.
	Deferred Offering Costs
	Incremental costs directly attributable to an offering of equity securities are deferred and charged against the gross proceeds of the offering as a reduction in owners’ equity, including underwriter fees, legal and accounting fees associated with the preparation of the registration statement, and other costs related to the promotion of the offering.  All other costs that are not directly related to the offering are expensed as incurred.
	Property and Equipment
	Property and equipment consist of land, land improvements, buildings, facilities, wells and equipment, computer and office equipment, and vehicles.  The Partnership records property and equipment at cost.  Costs of renewals and improvements that substantially extend the useful lives of the assets are capitalized.  Maintenance and repairs are expensed as incurred.  Depreciation for these assets is computed using the straight-line method over estimated useful lives.  Upon retirement, impairment or disposition of assets, the costs and related accumulated depreciation are removed from the accounts with the resulting gain or losses, if any, reflected in the Consolidated Statements of Operations.
	Debt Issuance Costs
	Debt issuance costs represent fees and expenses associated with securing the Partnership’s credit agreement (see Note 8).  Amortization of the capitalized debt issuance costs is computed using the effective interest method over the remaining estimated life of the credit agreement.
	Income Taxes
	As a limited partnership, we generally are not subject to federal, state or local income taxes.  The tax on the net income of the Partnership is generally borne by the individual partners.  Net income for financial statement purposes may differ significantly from taxable income of the partners as a result of differences between the tax basis and financial reporting basis of assets and liabilities and the taxable income allocation requirements under our partnership agreement.  The aggregated difference in the basis of our net assets for financial and tax reporting purposes cannot be readily determined because information regarding each partners’ tax attributes in us is not available to us.
	On December 9, 2013, the TIR Entities converted from corporate status to pass-through entities for U.S. federal income tax purposes.  The Partnership recorded tax expense of $15.0 million for income taxes associated with the gain on this conversion in the year ended December 31, 2013.  The TIR Entities that have Canadian activity remain taxable in Canada.  In addition, the Partnership has one subsidiary, Tulsa Inspection Resources – PUC, LLC (“TIR-PUC”), which has elected to be taxed as a corporation for U.S. federal income tax purposes.  The amounts recognized as income tax expense, income taxes payable, deferred tax assets and deferred tax liabilities on the Consolidated Financial Statements represent the Canadian and U.S. taxes referred to above, as well as partnership-level taxes levied by various states, primarily composed of franchise taxes assessed by the state of Texas.
	As a publicly traded limited partnership, we are subject to a statutory requirement that our "qualifying income" (as defined by the Internal Revenue Code, related Treasury Regulations, and Internal Revenue Service pronouncements) exceed 90% of our total gross income, determined on a calendar year basis. If our qualifying income does not meet this statutory requirement, we could be taxed as a corporation for federal and state income tax purposes. For the year ended December 31, 2014, the year we became a publicly traded limited partnership, our qualifying income met the statutory requirement.
	The Partnership evaluates uncertain tax positions for recognition and measurement in the Consolidated Financial Statements.  To recognize a tax position, the Partnership determines whether it is more likely than not that a tax position will be sustained upon examination, including resolution of any related appeals or litigation, based on the technical merits of the position.  A tax position that meets the more likely than not threshold is measured to determine the amount of benefit to be recognized in the Consolidated Financial Statements.  The amount of tax benefit recognized with respect to any tax position is measured as the largest amount of benefit that is greater than 50% likely of being realized upon settlement.  The Partnership had no uncertain tax positions that required recognition in the financial statements at December 31, 2014 or 2013.  Any interest or penalties would be recognized as a component of income tax expense.
	Revenue Recognition
	Revenues are recognized when there is persuasive evidence that an arrangement exists, delivery has occurred or services have been rendered, the price is fixed or determinable and collectability is reasonably assured.  Water disposal revenues are recognized upon receipt of the wastewater at our disposal facilities.  Oil disposal revenues are recognized when delivered to the customer and collectability is reasonably assured.
	Revenues related to pipeline inspection services are recognized when the services are provided and collectability is reasonably assured.  Generally, inspection services and use of provided equipment are billed on a per day basis.
	Unit-Based Compensation
	Our General Partner adopted a long-term incentive plan (“LTIP”) in connection with the IPO.  The cost of employee services received in exchange for equity instruments is measured based on the grant-date fair value of those instruments.  That cost is recognized straight-line over the requisite service period (often the vesting period) as discussed in Note 12.
	Net Income Per Unit
	We calculate basic net income per limited partner unit for each period by dividing net income by the weighted-average number of limited partner units outstanding. Diluted net income per limited partner unit for each period is the same calculation as basic net income per limited partner unit, except the weighted-average limited partner units outstanding includes the dilutive effect of phantom unit grants associated with our long-term incentive plan.
	The Company had a net loss for the year ended December 31, 2014.  As a result, all phantom restricted units were anti-dilutive and excluded from the weighted average units used in determining the loss per unit. There were 14,520 phantom restricted units that were excluded from the calculation of net income per unit as they were anti-dilutive.
	Accounts Receivable and Concentration of Credit Risk
	We operate in the United States and Canada.  We grant unsecured credit to customers under normal industry standards and terms, and have established policies and procedures that allow for an evaluation of each customer’s creditworthiness as well as general economic conditions.  The Partnership determines accounts receivable allowances based on management’s assessment of the creditworthiness of the customers and other collection actions.  Trade receivables are written off against the allowance when deemed uncollectible.  Recoveries of trade receivables previously written off are recorded when received.  The Partnership does not typically charge interest on past due trade receivables and does not require collateral for its trade receivables.  The Partnership had an allowance for doubtful accounts of $0.2 million at December 31, 2014 and 2013, and recorded bad debt expense of $0.1 million and $0.4 million for the years ended December 31, 2014 and 2013, respectively.  There was no bad debt expense recorded during the year ended December 31, 2012.
	We had two customers that each represented more than 10% of total accounts receivable as of December 31, 2014.  If one or more of these customers were to default on their payment obligations, we may not be able to replace any of these customers in a timely fashion, on favorable terms, or at all.
	Fair Value of Financial Instruments
	The carrying amounts reported in the Consolidated Balance Sheets for cash and cash equivalents, trade accounts receivable, accounts payable, accounts payable – affiliates, accrued payroll and other and income taxes payable approximate their fair values.
	Assets and Liabilities Measured at Fair Value on a Nonrecurring Basis
	Certain assets and liabilities are reported at fair value on a nonrecurring basis in the Partnership’s Consolidated Balance Sheets. The following methods and assumptions were used to estimate the fair values:
	Impairments of Property and Equipment
	The Partnership reviews its property and equipment and intangible assets for impairment whenever events or changes in circumstances indicate, in the judgment of management, that a decline in the recoverability of their carrying value may have occurred.  When an indicator of impairment has occurred, the Partnership compares its estimate of undiscounted cash flows attributable to the assets to the carrying value of the assets to determine whether an impairment has occurred.  If the estimate of undiscounted cash flows is less than the carrying value of the asset group, the Partnership determines the amount of the impairment recognized in the financial statements by estimating the fair value of the assets using a discounted cash flow model and records a loss for the amount by which the carrying value exceeds the estimated fair value.  Assets are grouped for impairment purposes at each SWD facility, which includes the well and supporting well equipment and infrastructure, as this represents the lowest level of cash flows associated with the asset group.  The Partnership recorded impairment losses of $12.8 and $3.4 million for the years ended December 31, 2014 and 2013, respectively (see Note 5).
	Goodwill
	At December 31, 2014 and 2013, the Partnership had $55.6 and $75.5 million of goodwill, respectively.  Goodwill is not amortized, but, is subject to annual reviews on November 1 for impairment at a reporting unit level.  The reporting unit or units used to evaluate and measure goodwill for impairment are determined primarily from the manner in which the business is managed or operated.  A reporting unit is an operating segment or a component that is one level below an operating segment.  In accordance with ASC 350 “Intangibles — Goodwill and Other”, we have assessed the reporting unit definitions and determined that at December 31, 2014 and 2013, W&ES and PI&IS, are the appropriate reporting units for testing goodwill impairment.  The accounting estimate relative to assessing the impairment of goodwill is a critical accounting estimate for each of our reporting segments.
	For our PI&IS reporting unit, we performed a qualitative assessment to determine whether the fair value of the reporting unit was more likely than not less than its carrying value.  Our evaluation consisted of assessing various qualitative factors including current and projected future earnings, capitalization, current customer relationships and projects and the impact of lower crude oil prices on our earnings.  The qualitative assessment on this reporting unit indicated that there was no need to conduct further quantitative testing for goodwill impairment nor did our analysis indicate the reporting unit was at risk for a potential goodwill impairment.  Different judgments from those we used in our qualitative analysis could result in the requirement to perform a quantitative goodwill impairment analysis.
	For our W&ES segment, after giving consideration to certain qualitative factors including trends in the energy industry and recorded impairments of property and equipment, we elected to perform a quantitative goodwill impairment analysis.  We computed the fair value of the reporting unit employing multiple valuation methodologies, including a market approach (market price multiples of comparable companies) and an income approach (discounted cash flow analysis).  This approach is consistent with the requirement to utilize all appropriate valuation techniques as described in ASC 820-10-35-24 “Fair Value Measurements and Disclosures. ” Given recent declines in the price of crude oil and the related impact on the valuations of energy related companies, relevant market data was difficult to obtain and was of limited usefulness.  Accordingly, we relied heavily on the use of the income approach for the valuation of the reporting unit.
	As a result of our valuation we determined that the carrying value of the W&ES reporting unit exceed the fair value of the reporting unit resulting in a goodwill impairment charge of $19.8 million.  The W&ES segment has experienced increased competition in some of the regions in which we operate which has resulted in declining volumes and increased pricing pressure.  The fourth quarter decline in oil prices has intensified competitive pressures and had a direct impact on our revenues.  Many of our customers have announced significantly reduced drilling programs in the areas in which we operate.  The decline in drilling will directly impact the amount of flowback and produced water that we process and dispose.  The energy downturn is also expected to continue to negatively impact our pricing as our customers look for ways to reduce costs.  In addition, as we process lower water volumes, in particular flowback water volumes directly attributable to drilling, we will recover less skim oil.  Lower oil prices will also directly impact revenues as oil sales have historically represented in excess of 20% of our W&ES revenues.
	Intangible Assets
	Intangible assets represent acquired customer relationships, trade names, and certain other intangibles acquired via various acquisitions and have been recorded utilizing various assumptions to determine fair market value including, but not limited to, replacement costs, liquidation values, future cash flows on a discounted basis of the net assets acquired, pay-off values, and average royalty rates.  Due to the unobservable nature of these assumptions, these fair value measurements are considered to be Level 3 fair value estimates.  Amortization of intangible assets is computed utilizing the straight-line method over their estimated useful lives, typically 5 – 20 years.
	We review our other intangible assets for impairment whenever events or changes in circumstances indicate we should assess the recoverability of the carrying amount of the intangible asset. We recognized no impairments for other intangible assets in 2014 and 2012. During 2013, the Partnership determined that one of its trade names in PI&IS had been impaired and identified that the fair value of the trade name, using an undiscounted cash flow model, was less than its carrying amount.  A $0.7 million adjustment was made to reduce the carrying value of the trade name to its fair value.  The fair value was calculated using a discounted cash flow model applied to the expected royalty values generated from the use of the trade name.  Management estimates of the future royalties associated with the use of the trade name were based on forecasted total revenues.  Actual results could vary materially from these estimates, which could have a further impact on the fair value of the trade name.
	Non-controlling Interest
	The Partnership holds a controlling interest in several entities which are not wholly owned.  The non-controlling interests shown in our Consolidated Balance Sheet at December 31, 2014 primarily includes the 49% membership interest in CES LLC that is owned by SBG Energy and the 49.9% interest in each of the TIR Entities that is owned by affiliates of Holdings.   Net income attributable to non-controlling interests shown in our Consolidated Statements of Operations reflects 49% of the net income of CES LLC for the years ended December 31, 2014 and 2013, and 49.9% of the net income of the TIR Entities for the period from our IPO through December 31, 2014.   The non-controlling interest in the TIR Entities is reduced by certain charges in accordance with our Partnership agreement.
	Business Combinations
	The Partnership evaluates all potential acquisitions and changes in control to determine whether it has purchased or acquired control of a business.  If the acquired or new controlled assets meet the definition of a business, it is accounted for as a business combination; otherwise it is accounted for as an asset acquisition.  Transactions discussed in Note 4 reflect business combinations for the periods described.
	Foreign Currency Translation
	The reporting currency is the U.S. dollar.  Non-U.S. dollar denominated monetary items are translated into U.S. dollars at the rate of exchange in effect at the balance sheet date.  Non-U.S. dollar denominated non-monetary items are translated to U.S. dollars at the exchange rate in effect when the transactions occur.  Revenues and expenses denominated in foreign currencies are translated at the exchange rate in effect during the period.  Foreign exchange gains or losses on translation are included in other comprehensive income.
New Accounting Standard
The Financial Accounting Standards Board issued Accounting Standards Update (“ASU”) 2014-09 – Revenue from Contracts with Customers in May 2014.  ASU 2014-09 is intended to clarify the principles for recognizing revenue and develop a common standard for recognizing revenue for GAAP and International Financial Reporting Standards that is applicable to all organizations.  The Partnership will be required to comply with this ASU beginning in 2017.  We are currently evaluating the impact of this ASU on the Partnership.  We do not anticipate that the adoption of this ASU will materially impact our financial position, results of operations or cash flows.

Note_3_Initial_Public_Offering

Note 3 - Initial Public Offering	12 Months Ended
	Dec. 31, 2014
Initial Public Offering [Abstract]
Initial Public Offering [Text Block]	3	Initial Public Offering
	On January 21, 2014, the Partnership completed its IPO consisting of 4,312,500 common units, representing limited partner interests in the Partnership at a price to the public of $20.00 per common unit ($18.70 per common unit, net of underwriting discounts, commissions and fees) which included a 562,500 unit over-allotment option that was exercised by the underwriters.  We received net proceeds of $80.2 million from the IPO, after deducting underwriting discounts and structuring fees.  The net proceeds from the IPO were distributed to Holdings II as reimbursement for certain capital expenditures it incurred with respect to assets contributed to us.
	Total deferred offering costs of $2.9 million, including costs incurred during the year ended December 31, 2014 of $0.3 million, were charged against the proceeds of the IPO.  In addition, the Partnership incurred $0.4 million and $1.4 million of offering costs during the years ended December 31, 2014 and 2013, respectively, that were expensed as incurred.  These non-recurring costs are reflected as offering costs in the Partnership’s Consolidated Statements of Operations.

Note_4_Business_Combinations

Note 4 - Business Combinations	12 Months Ended
	Dec. 31, 2014
Business Combinations [Abstract]
Business Combination Disclosure [Text Block]	4	Business Combinations
	2014 Business Combination
	SWD Acquisition
	Effective December 1, 2014, we acquired a recently constructed commercial SWD facility from SBG Energy (a related party) for a total purchase price of approximately $1.7 million. The facility had minimal operating activity prior to the acquisition.  The acquisition qualified as a business combination and was accounted for under the acquisition method of accounting.  Accordingly, we recognized amounts for identifiable assets acquired and liabilities assumed at their estimated acquisition date fair values.  The Partnership used various assumptions to determine fair value including, but not limited to, replacement costs, liquidation values and future cash flows on a discounted basis.  The acquisition was funded with borrowings from our credit facility.
	The fair value of the assets acquired and liabilities assumed were as follows:
			Fair Value
			(in thousands)
	Current assets		$	50
	Property and equipment			1,837
	Intangible assets - contracts			241
	Total value of assets acquired			2,128
	Current liabilities assumed			386
	Asset retirement obligation			1
	Net assets acquired		$	1,741
	In addition to the amounts reflected above, the Partnership anticipates incurring additional capital costs of up to $0.4 million to complete the SWD facility.
	2013 Business Combinations
	TIR Entities Acquisition
	As discussed in Note 2, Holdings acquired a controlling interest in the TIR Entities on June 26, 2013.  This transaction qualified as a business combination and therefore the assets and liabilities were recorded at their fair value under the acquisition method of accounting.  Holdings used various assumptions to determine fair value including, but not limited to, replacement costs, liquidation values, future cash flows on a discounted basis, pay-off values and average industry royalty rates.  Due to the unobservable nature of these assumptions, these fair value measurements are considered to be Level 3 fair value estimates.
	The fair value of the assets and liabilities acquired as of June 26, 2013 were as follows:
			Fair Value
			(in thousands)
	Cash		$	10,108
	Other working capital, net			33,990
	Property and equipment			1,075
	Intangible assets:
	Trade names and trademarks			10,850
	Inspector database			2,080
	Customer relationships			21,380
	Goodwill			40,638
	Total value of assets acquired			120,121
	Mezzanine debt			19,756
	Factoring debt			36,748
	Total liabilities assumed			56,504
	Net assets acquired		$	63,617
	SBG Disposal Acquisition
	Effective October 1, 2013, the Partnership acquired certain assets including certain property and equipment, SWD facility management contracts, including contracts to provide services to the Partnership’s SWD facilities, a 25% interest in a SWD facility and certain working capital from SBG Disposal LLC, a subsidiary of SBG Energy, in exchange for $0.5 million from available cash on hand and a 49% ownership in CES LLC.  In conjunction with the SBG Acquisition discussed below, the Partnership had previously assigned a fair value of $0.2 million to its option to purchase these assets.  The exercise of the option, along with the cash purchase price, totaled $0.7 million.  In addition, the 49% interest in CES LLC had a fair value of $0.7 million resulting in total consideration of $1.4 million.
	The acquisition qualified as a business combination and was accounted for under the acquisition method of accounting.  Accordingly, we recognized amounts for identifiable assets acquired and liabilities assumed at their estimated acquisition date fair values.  The Partnership used a discounted cash flow model to value the customer relationships and the 25% interest in the SWD facilities and made market assumptions for the estimation of future water to be disposed of as discussed in Note 2.  The Partnership also used an estimate of replacement cost to value the acquired property and equipment.  Due to the unobservable nature of the inputs, these estimates of the fair value of the acquired wells are considered Level 3 fair value estimates.  The purchase price and assessment of the fair value of the assets acquired and liabilities assumed for the SBG Disposal acquisition were as follows:
			Fair Value
			(in thousands)
	Current assets		$	35
	Property and equipment			300
	Intangible assets - customer relationships			150
	Goodwill			971
	Total assets acquired			1,456
	Current liabilities			35
	Net assets acquired		$	1,421
	The customer relationships are amortized over a five year period.
	2012 Business Combinations
	Moxie Acquisition
	In December 2012, the Partnership acquired four commercial SWD facilities through two agreements for a total purchase price of approximately $23.9 million, subject to customary adjustments.  The acquisitions were funded with available cash from member equity contributions.  The effective date of the acquisition was December 3, 2012, and the Partnership took over operations of the wells on December 4, 2012.
	SBG Acquisition
	In December 2012, the Partnership acquired 100% of the interests in six operating commercial SWD facilities, one under-construction commercial SWD facility, an option to acquire a 51% interest in certain assets of SBG Disposal, LLC for $0.5 million, including a 25% ownership interest in an LLC that owns and operates a SWD facility (“Purchase Option”) and various other rights of first refusal to purchase other businesses and assets from SBG Energy.  The Partnership assigned a fair value of $0.2 million to the Purchase Option which was exercised on October 1, 2013.  The total purchase price was approximately $47.3 million, net of customary adjustments.  One of these customary adjustments included the requirement of SBG Energy to include $8.2 million for a series of well improvement and construction reserves, which effectively reduced the purchase price.  Any future capital obligations related to these well improvements or new SWD facility construction projects are the responsibility of the Partnership.  The acquisition was funded with available cash from member equity contributions.  The closing date of the acquisition was December 31, 2012.
	The Moxie Acquisition and the SBG Acquisition qualified as business combinations and were accounted for under the acquisition method of accounting.  The Partnership recorded the assets acquired and liabilities assumed at their estimated fair market values as of the closing dates.  The fair value is the price that would be received to sell an asset or paid to transfer a liability in an orderly transaction between market participants at the measurement date.
	Fair value measurements also utilize the following primary assumptions of market participants.  To estimate the fair value of the acquired SWD facilities, the Partnership used a discounted cash flow model and made market assumptions for the estimation of future water to be disposed of due to oil and gas drilling and production volumes in the markets served, risks associated with the different zones into which salt water is disposed, expected future disposal rates and commodity prices, capital expenditures, operating costs, and appropriate discount rates.  Due to the unobservable nature of the inputs, these estimates of the fair value of the acquired wells are considered Level 3 fair value measurements.
	The purchase price and assessment of the fair value of the assets acquired and liabilities assumed for the Moxie Acquisition and the SBG Acquisition, which included certain properties not contributed to the Partnership, were as follows:
			Moxie Acquisition			SBG Acquisition		Total
			( in thousands )
	Fair value of net assets:
	Current assets		$	288		$	2,947	$	3,235
	Property and equipment			16,634			30,017		46,651
	Related-party notes receivable			—			438		438
	Intangible assets			60			225		285
	Goodwill			6,903			26,974		33,877
	Total assets acquired			23,885			60,601		84,486
Current liabilities			—			500		500
Related-party notes payable			—			1,534		1,534
Contingent consideration due sellers			—			11,250		11,250
Asset retirement obligations			3			5		8
Total liabilities assumed			3			13,289		13,292
Total purchase price		$	23,882		$	47,312	$	71,194
Contingent consideration was due to sellers based upon the acquired assets meeting certain profitability thresholds for 2013.  Management’s initial estimate was that the sellers would be due $11.25 million based upon achieving 50% of their maximum possible results by attaining $12.8 million in 2013 EBITDA (earnings before income taxes, depreciation, and amortization) on the acquired SWD facilities.  Accordingly, the Partnership recorded a liability for the contingent consideration totaling $11.25 million.  During the second quarter of 2013, management estimated that the financial results would be below the minimum threshold for the seller to earn any contingent consideration based on the actual performance of these wells for 2013 and the forecasted EBITDA for the remaining of the year.  The contingent liability was reversed in full during the second quarter 2013 and is recorded in the Consolidated Statements of Operations as a gain on reversal of contingent consideration.  The EBITDA forecast is considered a Level 3 fair value measurement.
Intangible assets consist primarily of various 36-month non-compete agreements associated with the Moxie Acquisition to which the Partnership has assigned a fair value of $0.1 million, as well as the $0.2 million Purchase Option discussed above which was contributed to the SBG Disposal Acquisition.  The non-compete agreements are being amortized ratably over three years.
Goodwill for the Moxie and SBG transactions represents the excess of cost over the fair value of identified assets, liabilities, and contingent liabilities.  The Partnership believed the locations, synergies created by combining these entities, and the projected future cash flows of the acquired entities merit the recognition of this asset.  The goodwill is fully deductible for tax purposes by our partners.
The following summarized pro forma information for the years ended December 31, 2014, 2013 and 2012 presents the combined results of the Partnership as if the business combinations occurred as of the later of January 1, 2012 or the initiation of operations of the acquired business:
		2014			2013		2012
		( in thousands )
Revenue as reported		$	404,418		$	249,133	$	619
Business Combinations:
SWD Facility			297			-		-
TIR Entities Acquisition			-			152,989		233,803
SBG Disposal Acquisition			-			814		-
SBG Acquisition			-			-		8,588
Moxie Acquisition			-			-		3,180
Pro-forma revenue		$	404,715		$	402,936	$	246,190
Net income (loss) as reported		$	(15,179	)	$	4,355	$	(1,845	)
Business Combinations:
SWD Facility			(213	)		-		-
TIR Entities Acquisition			-			953		2,662
SBG Disposal Acquisition			-			127		-
SBG Acquisition			-			-		4,462
Moxie Acquisition			-			-		1,391
Pro-forma net income (loss)		$	(15,392	)	$	5,435	$	6,670
These pro forma results are for comparative purposes only and may not be indicative of the results that would have occurred had the acquisitions been completed on the later of  January 1, 2012 or the commencement date of the acquired business, or the results that may be attained in the future.

Note_5_Property_and_Equipment

Note 5 - Property and Equipment	12 Months Ended
	Dec. 31, 2014
Property, Plant and Equipment [Abstract]
Property, Plant and Equipment Disclosure [Text Block]	5	Property and Equipment
	Property and equipment consist of the following, recorded at cost, as of December 31, 2014 and 2013:
						December 31,
	Asset Category		Useful Lives			2014			2013
						( in thousands )
	Land					$	2,049		$	2,049
	Land improvements		15 years				1,143			2,543
	Buildings and leasehold improvements		39 years				1,056			1,767
	Facilities, wells, and equipment		5 – 15 years				22,666			35,326
	Computer and office equipment		3 – 9 years				816			771
	Other		3 – 5 years				148			73
							27,878			42,529
	Less accumulated depreciation						(3,538	)		(3,711	)
	Net property and equipment					$	24,340		$	38,818
	Depreciation expense is computed using the straight-line method over the estimated useful lives of the assets.  Depreciation expense was $4.1 million, $4.1 million and $0.1 million for the Partnership for the years ended December 31, 2014, 2013 and 2012, respectively, of which $0.2 million and $0.1 million was included as a component of costs of services for the years ended December 31, 2014 and 2013.  Depreciation expense for the Predecessor in 2012 was $1.2 million.  Additionally, as a result of our impairment analysis, we wrote down the value of certain property and equipment which resulted in a decrease of accumulated depreciation of $4.3 million $0.6 million in 2014 and 2013, respectively.
	During 2014, the Partnership recorded impairments of property and equipment at five of its SWD facilities.  At each of these facilities, the Partnership experienced revenue and volume decreases due to lower commodity markets and increasing competition and has forecasted decreases in drilling activity affecting volumes and revenues over the remaining life of the underlying assets.  Given these indicators of impairment, the Partnership compared its estimate of undiscounted future cash flows from the facilities to the carrying amount of the long-lived assets of the facilities, and determined they were no longer recoverable and were impaired.
	The Partnership wrote these facility’s assets down from their net carrying value of $20.0 million to their estimated fair value of $7.2 million and recognized an impairment on the facilities totaling $12.8 million included in the impairments caption on the Consolidated Statement of Operations for the year ended December 31, 2014.
	During 2013, the Partnership recorded impairments at one of its SWD facilities.  The Partnership experienced declining revenues and operating losses at this SWD facility since acquiring the facility on December 31, 2012 due to increased competition in proximity to the facility.  Given these impairment indicators, the Partnership compared its estimate of undiscounted future cash flows from the facility to the carrying amount of the long-lived assets of the facility, and determined that they were no longer recoverable and were impaired.
	The Partnership wrote the facility assets down from their net carrying value of $4.5 million to their estimated fair value of $1.1 million and recognized an impairment of the facility totaling $3.4 included in the impairments caption on the Consolidated Statement of Operations for the year ended December 31, 2013.
	The following table shows the impaired property and equipment by category:
			Year Ended December 31,
			2014			2013
			(in thousands)
	Asset Category
	Land improvements		$	1,514		$	725
	Buildings and leasehold improvements			748			135
	Facilities, wells and equipment			14,796			2,964
				17,058			3,824
	Accumulated depreciation			(4,285	)		(397	)
	Impairment of facilities		$	12,773		$	3,427
	Fair value was determined using expected future cash flows, which is a Level 3 input as defined in Accounting Standards Codification (“ASC”) 820, Fair Value Measurement.  The cash flows are those expected to be generated by the market participants, discounted at the Partnership’s estimated cost of capital.  Because of the uncertainties surrounding the repair of the facility and the market conditions, including the Partnership’s ability to generate and maintain sufficient revenues to operate the facility profitably, our estimate of expected future cash flows may change in the near term resulting in the need to further adjust our determination of fair value.

Note_6_Goodwill

Note 6 - Goodwill	12 Months Ended
	Dec. 31, 2014
Disclosure Text Block Supplement [Abstract]
Goodwill Disclosure [Text Block]	6	Goodwill
	Goodwill represents the excess of cost over fair value of the assets and liabilities of businesses acquired.  Changes in goodwill are as follows:
			W&ES			PI&IS			Total
			(in thousands)
	Balance - December 31, 2012		$	33,877		$	-		$	33,877
	Goodwill from business combinations			971			40,638			41,609
	Foreign currency translation			-			(20	)		(20	)
	Balance - December 31, 2013			34,848			40,618			75,466
	Impairments			(19,773	)		-			(19,773	)
	Foreign currency translation			-			(148	)		(148	)
	Balance - December 31, 2014		$	15,075		$	40,470		$	55,545
	Goodwill is not amortized, but is subject to annual reviews on November 1 for impairment at a reporting unit level.  The reporting unit or units used to evaluate and measure goodwill for impairment are determined primarily from the manner in which the business is managed or operated.  A reporting unit is an operating segment or a component that is one level below an operating segment.  In accordance with ASC 350 “Intangibles — Goodwill and Other”, we have assessed the reporting unit definitions and determined that at December 31, 2014 and 2013, W&ES and PI&IS, are the appropriate reporting units for testing goodwill impairment.  The accounting estimate relative to assessing the impairment of goodwill is a critical accounting estimate for each of our reporting segments.
	For our PI&IS reporting unit, we performed a qualitative assessment to determine whether the fair value of the reporting unit was more likely than not less than its carrying value.  Our evaluation consisted of assessing various qualitative factors including current and projected future earnings, capitalization, current customer relationships and projects and the impact of lower crude oil prices on our earnings.  The qualitative assessment on this reporting unit indicated that there was no need to conduct further quantitative testing for goodwill impairment nor did our analysis indicate the reporting unit was at risk for a potential goodwill impairment.  Different judgments from those we used in our qualitative analysis could result in the requirement to perform a quantitative goodwill impairment analysis.
	For our W&ES segment, after giving consideration to certain qualitative factors including trends in the energy industry and recorded impairments of property and equipment, we elected to perform a quantitative goodwill impairment analysis.  We computed the fair value of the reporting unit employing multiple valuation methodologies, including a market approach (market price multiples of comparable companies) and an income approach (discounted cash flow analysis).  This approach is consistent with the requirement to utilize all appropriate valuation techniques as described in ASC 820-10-35-24 “Fair Value Measurements and Disclosures.” Given recent declines in the price of crude oil and the related impact on the valuations of energy related companies, relevant market data was difficult to obtain and was of limited usefulness.  Accordingly, we relied heavily on the use of the income approach for the valuation of the reporting unit.
	As a result of our valuation, we determined that the carrying value of the W&ES reporting unit exceeded the fair value of the reporting unit resulting in a goodwill impairment charge of $19.8 million.  The W&ES segment has experienced increased competition in some of the regions in which we operate which has resulted in declining volumes and increased pricing pressure.  The fourth quarter decline in oil prices has intensified competitive pressures and had a direct impact on our revenues.  Many of our customers have announced significantly reduced drilling programs in the Bakken.  The decline in drilling will directly impact the amount of flowback and produced water that we process and dispose.  The energy downturn is also expected to continue to negatively impact our pricing as our customers look for ways to reduce costs.  In addition, as we process lower water volumes, in particular flowback water volumes directly attributable to drilling, we will recover less skim oil.  Lower oil prices will also directly impact revenues as oil sales have historically represented in excess of 20% of our W&ES revenues.

Note_7_Intangible_Assets

Note 7 - Intangible Assets	12 Months Ended
	Dec. 31, 2014
Disclosure Text Block [Abstract]
Intangible Assets Disclosure [Text Block]	7	Intangible Assets
	Intangible assets consist of the following at December 31, 2014 and 2013:
					31-Dec-14				31-Dec-13
			Useful		Gross		Accumulated		Gross		Accumulated
			Lives		Carrying		Amortization		Carrying		Amortization
					Amount				Amount
					( in thousands )
	Customer relationships		5-20 years		$	21,510	$	1,788	$	21,510	$	554
	Contracts		3 years			241		-		-		-
	Non-compete agreements		3 years			60		41		60		21
	Trademarks and trade names		10 years			10,135		1,638		10,135		553
	Inspector database		10 years			2,080		314		2,080		106
	Total				$	34,026	$	3,781	$	33,785	$	1,234
	Amortization expense for the years ended December 31, 2014 and 2013 was $2.4 million and $1.3 million respectively. There was no amortization expense for the year ended December 31, 2012.
	Future amortization expense of our intangible assets is estimated to be as follows:
	Year Ending December 31,		( in thousands )
	2015		$	2,468
	2016			2,391
	2017			2,391
	2018			2,305
	2019			2,281
	Thereafter			18,409
			$	30,245
	During the year ended December 31, 2013, the Partnership determined that one of its trade names in PI&IS was impaired and recorded an impairment charge of $0.7 million.

Note_8_Credit_Agreement

Note 8 - Credit Agreement	12 Months Ended
	Dec. 31, 2014
Debt Disclosure [Abstract]
Debt Disclosure [Text Block]	8	Credit Agreement
	On December 24, 2013, the Partnership and our affiliate, Cypress Energy Partners – TIR, LLC (“CEP-TIR”), (together, the “Borrowers”), entered into a $120.0 million secured credit agreement (the “Credit Agreement”) as co-borrowers and co-guarantors with a syndicate of banks that consists of a $65.0 million senior secured working capital revolving credit facility and a $55.0 million senior secured acquisition revolving credit facility.  On October 21, 2014, the credit agreement was amended to increase the aggregate availability under the credit agreement from $120.0 million to $200.0 million and extended the maturity date to December 24, 2018.  Availability under the acquisition revolving credit facility was increased to $125.0 million and availability under the working capital revolving credit facility was increased to $75.0 million.  In addition, the amendment provides for an accordion feature that allows us to increase availability under the facilities by an additional $125.0 million.
	At December 31, 2014 and 2013, there were outstanding borrowings under the credit agreement of $77.6 million and $75.0 million, respectively reflected on the Consolidated Balance Sheets as long-term debt. Borrowings under the credit agreement are due at maturity.  If, at any time, outstanding borrowings exceed the combined borrowing base of the Borrowers, principal in the amount of the excess is due upon submission of the borrowing base calculation.  Certain conditions defined in the Credit Agreement limit our access to the acquisition revolving credit facility to $89.7 million of the total $97.4 million available and $15.3 million of the total available $25.0 million under the working capital revolving credit facility at December 31, 2014.  Certain circumstances, such as additional acquisitions, could offset the defined limitations and provide the Partnership the opportunity to fully access the stated borrowing limitations on the Credit Agreement. The obligations under our Credit Agreement are secured by a first priority lien on substantially all assets of the Borrowers.
	All borrowings under the Credit Agreement bear interest, at our option, on a leveraged based grid pricing at (i) a base rate plus a margin of 1.25% to 2.75% per annum (“Base Rate Borrowing”) or (ii) an adjusted LIBOR rate plus a margin of 2.25% to 3.75% per annum (“LIBOR Borrowings”). The applicable margin is determined based on the combined leverage ratio of the Borrowers, as defined in the Credit Agreement.  At December 31, 2014 and 2013, the interest rate in effect on outstanding LIBOR Borrowings was 3.03% and 3.14%, respectively, calculated as the weighted average LIBOR rate of 0.255% in 2014 and 0.225% in 2013 plus a weighted average margin of 2.77% in 2014 and 2.92% in 2013.  There were no Base Rate Borrowings outstanding at December 31, 2014 or 2013.  Interest on Base Rate Borrowings is payable monthly.  Interest on LIBOR Borrowings is paid upon maturity of the underlying LIBOR contract, but no less often than quarterly.  Commitment fees are charged at a rate of 0.50% on any unused credit and payable quarterly.
	Our Credit Agreement contains various customary affirmative and negative covenants and restrictive provisions.  Our Credit Agreement also requires maintenance of certain financial covenants, including a combined total adjusted leverage ratio (as defined in our Credit Agreement) of not more than 4.0 to 1.0 and an interest coverage ratio (as defined in our Credit Agreement) of not less than 3.0 to 1.0.  At December 31, 2014, our total adjusted leverage ratio was 0.94 to 1.0 and our interest coverage ratio was 9.14 to 1.0.  Upon the occurrence and during the continuation of an event of default, subject to the terms and conditions of our Credit Agreement, the lenders may declare any outstanding principal of our Credit Agreement debt, together with accrued and unpaid interest, to be immediately due and payable and may exercise the other remedies set forth or referred to in our Credit Agreement. We expect to remain in compliance with all or our financial debt covenants throughout 2015.
	In addition, our Credit Agreement restricts our ability to make distributions on, or redeem or repurchase our equity interests, provided, however, that we may make distributions of available cash so long as, both at the time of the distribution and after giving effect to the distribution, no default exists under our Credit Agreement, the borrowers and the guarantors are in compliance with the financial covenants, the borrowing base (which includes 100% of cash on hand) exceeds the amount of outstanding credit extensions under the working capital revolving credit facility by at least $5.0 million and at least $5.0 million in lender commitments are available to be drawn under the borrowing base revolving credit facility.  The combined calculated borrowing base of the Borrowers was $65.3 million at December 31, 2014 which represents our maximum availability under the working capital revolving credit facility as of that date.  Availability under the acquisition revolving credit facility is not subject to a borrowing base calculation but is restricted by our maximum leverage calculation. Borrowings under the Credit Agreement are due at maturity.  If at any time outstanding borrowings under the working capital facility exceed the combined borrowing base of the Borrowers, principal in the amount of the excess is due upon submission of the borrowing base calculation.
	The following table reflects the changes in long-term debt during the year:
			December 31,		Net borrowings		December 31,
			2013		or		2014
					repayments
			(in thousands)
	Acquisition revolving credit facility
	(3.26% at December 31, 2014)		$	25,000	$	2,600	$	27,600
	Borrowing base revolving credit facility
	(2.74% at December 31, 2014)			50,000		-		50,000
	Total long-term debt		$	75,000	$	2,600	$	77,600

Note_9_Income_Taxes

Note 9 - Income Taxes	12 Months Ended
	Dec. 31, 2014
Income Tax Disclosure [Abstract]
Income Tax Disclosure [Text Block]	9	Income Taxes
	As a limited partnership, we generally are not subject to federal, state or local income taxes.  The tax on the net income of the Partnership is generally borne by the individual partners.  We have Canadian activity that remains taxable in Canada.  In addition, effective January 1, 2014, we formed a wholly owned subsidiary, Tulsa Inspection Resources – PUC, LLC (“TIR-PUC”), which has elected to be taxed as a corporation for U.S. federal income tax purposes.  The amounts recognized as income tax expense, income taxes payable, deferred tax assets and deferred tax liabilities on the Consolidated Financial Statements represent the Canadian and U.S. taxes referred to above, as well as partnership-level taxes levied by various states.  We are also subject to certain margin based taxes in some states.
	From January 1, 2013 to December 9, 2013, Tulsa Inspection Resources, Inc. (“TIR Inc.”), the predecessor of the TIR Entities, operated as a taxable corporation.  On December 9, 2013, TIR Inc. converted to a Limited Liability Company (“LLC”).
	The Partnership recognized a one-time tax provision of $15.0 million associated with the gain on the deemed sale of TIR Inc. associated with the conversion to a pass-through entity. To calculate the gain on conversion, the Partnership determined the fair value of the assets and liabilities as of the date of conversion.  We used various assumptions to determine fair value including, but not limited to, estimating replacement costs, liquidation values, future cash flows on a discounted basis, pay-off values and average industry royalty rates.  Due to the unobservable nature of the assumptions used in the valuation analysis, these fair value measurements are considered to be Level 3 fair value measurements.  The resulting fair value of TIR Inc. was used as the hypothetical proceeds under the deemed sale at conversion and the tax provision was calculated on the resulting gain.  The tax expense associated with the conversion of TIR Inc. on December 9, 2013 is included in income tax expense on the Consolidated Statement of Operations for the year ended December 31, 2013 and income taxes payable on the Consolidated Balance Sheet as of December 31, 2013.
	Significant components of income tax expense (benefit) are as follows for the years ended December 31:
			2014			2013
			(in thousands)
	Current expense:
	Federal		$	38		$	14,714
	State			332			2,462
	Canadian			100			285
	Total			470			17,461
	Deferred tax expense (benefit):
	Federal			(12	)		(1,553	)
	State			(3	)		(390	)
	Canadian			13			(281	)
	Total			(2	)		(2,224	)
	Total income tax expense		$	468		$	15,237
	There was no income tax expense recorded for the year ended December 31, 2012.
	The deferred tax assets and liabilities of the Partnership consisted of the following:
			Year Ended December 31,
			2014			2013
			(in thousands)
	Current deferred tax assets:
	Accrued liabilities		$	17		$	1
	Bad debt reserve			-			28
	Canadian net operating loss			51			105
	Total		$	68		$	134
	Non-current deferred tax assets (liabilities):
	Property and equipment		$	2		$	3
	Intangible assets			(440	)		(544	)
	Total		$	(438	)	$	(541	)
	The Canadian net operating loss expires in 2025 and as such, the Partnership has made no valuation allowance against this deferred tax asset as of December 31, 2014 or 2013.
	The following table reconciles the differences between the U.S. federal statutory rate of 35% to the Partnership’s income tax expense on the Consolidated Statements of Operations for the years ended December 31:
			2014			2013			2012			Predecessor
												2012
						(in thousands)
	Tax (benefit) computed at statutory rate of 35%		$	(5,149	)	$	6,857		$	(646	)	$	2,170
	Income not subject to federal taxes			5,274			(4,793	)		646			(2,170	)
	State income taxes, net of federal benefit			326			535			-			-
	Tax on conversion of TIR, Inc. to pass through entities			-			12,892			-			-
	Other			17			(254	)		-			-
	Total income tax expense		$	468		$	15,237		$	-		$	-
	Tax years that remain subject to examination by various taxing authorities for each of our consolidated entities include the years 2011 through 2013.

Note_10_Parent_Net_Investment_

Note 10 - Parent Net Investment and Owners' Equity	12 Months Ended
	Dec. 31, 2014
Stockholders' Equity Note [Abstract]
Stockholders' Equity Note Disclosure [Text Block]	10	Parent Net Investment and Owners’ Equity
	Parent Net Investment
	For the periods prior to the IPO, the net equity of the contributed entities is included in parent net equity in the Consolidated Balance Sheet as of December 31, 2013. Also, prior to the IPO, CEP LLC provided treasury and accounts payable services for Holdings and other affiliates.  Amounts paid on behalf of Holdings and its affiliates, net of cash transfers from Holdings, are included as a component of parent net equity.  Cumulative advances for the periods prior to the IPO as of December 31, 2014, 2013 and 2012 were $0.2 million, $3.5 million and $0.5 million, respectively.
	Common Units and Subordinated Units
	As of December 31, 2014, there are 5,913,000 common units and 5,913,000 subordinated units outstanding.  Items of income / loss are allocated to common units and subordinated units equally.  The common unitholders will have the right to receive the minimum quarterly cash distributions of $0.3875 per common unit, plus any arrearages in the payment of the minimum quarterly distributions on the common units from prior quarters, before any distributions of available cash may be made on the subordinated units.  These units are deemed “subordinated” because, for the subordination period as defined in our offering documents, the subordinated units will not be entitled to receive any distributions until the common units have received the minimum quarterly distribution plus any arrearages from prior quarters.  Furthermore, no arrearages will be paid on the subordinated units.  For the year ended December 31, 2014, there were no limitations or arrearages related to the quarterly distributions made by the Partnership.
	Incentive Distribution Rights
	Our General Partner owns a 0.0% non-economic general partnership interest in the Partnership, which does not entitle it to receive cash distributions.  Our General Partner holds incentive distribution rights (“IDRs”), which represent the right to receive an increasing percentage (15%, 25% and 50%) of quarterly distributions of available cash from operating surplus after the minimum quarterly distribution and target distribution levels have been achieved. The General Partner would begin receiving incentive distribution payments when the quarterly cash distribution exceeds $0.445625 per unit.  There were no incentive distribution payments in 2014.

Note_11_Major_Customers

Note 11 - Major Customers	12 Months Ended
	Dec. 31, 2014
Risks and Uncertainties [Abstract]
Concentration Risk Disclosure [Text Block]	11	Major Customers
	For the year ended December 31, 2014, three customers individually exceeded 10% of our consolidated total revenues: Enbridge Energy Partners, Enterprise Products Partners and Plains All America Pipeline.  For the year ended December 31, 2013, Enbridge Energy Partners and Enterprise Products Partners each individually made up more than 10% of total consolidated revenues.  No other customer accounted for more than 10% of our consolidated revenues during these years. Revenues from these customers resulted from inspection operations, which are activities conducted by our PI&IS segment.

Note_12_Equity_Compensation

Note 12 - Equity Compensation	12 Months Ended
	Dec. 31, 2014
Disclosure of Compensation Related Costs, Share-based Payments [Abstract]
Disclosure of Compensation Related Costs, Share-based Payments [Text Block]	12	Equity Compensation
	Partnership Long-Term Incentive Plan (“LTIP”)
	Effective at the closing of the IPO, our General Partner adopted an LTIP that authorized up to 1,182,600 units representing 10% of the initial outstanding units.  Certain directors and employees of the Partnership have been awarded Phantom Restricted Units (“Units”) under the terms of the LTIP.  The fair value of the awards issued is determined based on the quoted market value of the publically traded common units at each grant date, adjusted for a forfeiture rate, and other discounts attributable to the awarded units.  This valuation is considered a Level 3 measurement under the fair value measurement hierarchy.  Compensation expense is recognized straight-line over the vesting period of the grant.  Holdings reimburses the Partnership for the direct expense of the awards and allocates the expense to us through the annual administrative fee provided for under the terms of our amended and restated omnibus agreement (Note 13).  For the year ended December 31, 2014, compensation expense of $0.5 million was recorded under the LTIP.  The following table sets forth the grants and forfeitures of Units under the LTIP for the year ended December 31, 2014:
			Number			Weighted
			of Units			Average
						Grant
						Date Fair
						Value / Unit
	Units at January 1, 2014			-		$	-
	Units granted			178,264			17.96
	Units forfeited			(19,911	)		(16.78	)
	Units at December 31, 2014			158,353			17.36
	Outstanding Units issued to directors vest ratably over a three-year period from the date of grant.  Units granted to employees vest over a five-year period from the date of grant, with one third vesting at the end of the third year, one third at the end of the fourth year and one third vesting at the end of the fifth year or will vest in full upon the occurrence of a Fundamental Change, as defined in the LTIP agreement. Total unearned compensation associated with the LTIP at December 31, 2014 was $2.1 million with an average remaining life of 3.9 years.
	In conjunction with the IPO, phantom profits interest units previously issued under a CEP LLC LTIP were exchanged for 44,250 Units under the LTIP.  Vesting under all of the exchanged awards is retroactive to the initial grant date.  The awards will be considered for all purposes to have been granted under the Partnership’s LTIP.  In addition, at IPO, certain profits interest units previously issued under CEP LLC’s LTIP were converted into 44,451 subordinated units of the Partnership outside of the LTIP.  Vesting for the subordinated units is retroactive to the initial grant date.  Compensation expense associated with the subordinated units was $0.3 million for the year ended December 31, 2014.  The exchange of the phantom profits interest units and the profits interest units resulted in the reversal of the existing equity compensation liability of $0.1 million in the first quarter of 2014 as the new awards are accounted for as equity. The unearned compensation related to the subordinated units was $0.5 million with an average remaining life of 3.1 years.
	TIR Entities Stock Option Plan
	On January 1, 2011, TIR Inc., executed a Stock Option Plan to allow certain share based compensation to be issued to employees, non-employee directors and contractors.  Under the plan, TIR Inc. could award up to 14 shares of common stock from authorized unissued shares or shares held in treasury.  At the discretion of the administrator of the Stock Option Plan, employees, non-employee directors and consultants may be granted awards in the form of incentive stock options, non-qualified stock options or restricted shares, any of which may be service, market or performance based awards. Total compensation expense recognized related to the non-qualified stock options issued was $0.2 million for the period from June 26, 2013 through December 31, 2013.
	During 2013, the TIR Entities’ board authorized the vesting of certain management options.  Management opted to execute the vested options using a cashless exercise, net of employee owed taxes, after which the issued shares were subsequently sold to CEP-TIR.  TIR Inc. paid the employee taxes owed of $0.6 million, recording the payment as a purchase of treasury shares.  The shares were purchased from the employees at their estimated fair value, which was determined based on several factors including the average price of recent share transactions between affiliated and non-affiliated parties. Compensation expense was recognized for the excess of the fair value of the shares received over the price paid for the shares, totaling $1.75 million.  The tax benefit associated with the employee compensation totaled $0.7 million, of which $0.2 million was included in the 2013 tax provision, offsetting the cumulative tax benefit from compensation expense previously recorded by TIR Inc.  The remaining $0.5 million, representing the additional tax benefit in excess of the tax benefit from options previously expensed by TIR Inc., is included as a reduction of equity.  Additionally, certain management options were forfeited as a result of the conversion of TIR Inc. to a pass-through entity on December 9, 2013.
	Option activity and changes during 2013 were as follows:
			Quantity			Intrinsic Value
			( in shares )			( in thousands )
	Outstanding at June 26, 2013			7		$	2,450
	Granted			-			-
	Exercised			(5	)		(1,750	)
	Forfeited or expired			(2	)		(700	)
	Outstanding at December 31, 2013			-		$	-

Note_13_RelatedParty_Transacti

Note 13 - Related-Party Transactions	12 Months Ended
	Dec. 31, 2014
Related Party Transactions [Abstract]
Related Party Transactions Disclosure [Text Block]	13	Related-Party Transactions
	Omnibus Agreement
	Effective, as of the closing of the IPO, we entered into an omnibus agreement with Holdings and other related parties.   The omnibus agreement, which was amended and restated in February 2015 to reflect the acquisition of the remaining interests in the TIR Entities, governs the following matters, among other things:
		●	our payment of an annual administrative fee, initially in the amount of $4.0 million to be paid in quarterly installments (pro-rated in 2014 from the IPO date) to Holdings for providing certain partnership overhead services, including certain executive management services by certain officers of our General Partner, and compensation expense (including equity-based compensation) for all employees required to manage and operate our business.  This fee also includes the incremental general and administrative expenses we incur as a result of being a publicly traded partnership;
		●	limitations on the amount of indebtedness CEP-TIR may incur under our credit agreement and the allocation of certain interest expenses to the TIR Entities;
		●	our right of first offer on Holdings’ and its subsidiaries’ assets used in, and entities primarily engaged in, providing SWD and other water and environmental services and pipeline inspection and integrity services; and
		●	indemnification of us by Holdings for certain environmental and other liabilities, including events and conditions associated with the operation of assets that occurred prior to the closing of the IPO and our obligation to indemnify Holdings for events and conditions associated with the operation of our assets that occur after the closing of the IPO and for environmental liabilities related to our assets to the extent Holdings is not required to indemnify us.
	So long as Holdings controls our General Partner, our amended and restated omnibus agreement will remain in full force and effect, unless we and Holdings agree to terminate it sooner.  If Holdings ceases to control our General Partner, either party may terminate our amended and restated omnibus agreement, provided that the indemnification obligations will remain in full force and effect in accordance with their terms.  We and Holdings may agree to further amend our amended and restated omnibus agreement; however, amendments that the General Partner determines are adverse to our unitholders will also require the approval of the Conflicts Committee of our Board of Directors.
	The amount charged by Holdings under the omnibus agreement for the year ended December 31, 2014 was $3.8 million and is reflected in general and administrative in the Consolidated Statements of Operations.  Additional expenses were incurred by Holdings in support of the Partnership totaling $0.5 million. These expenses were also allocated to the Partnership and are reflected in general and administration and as an equity contribution.
	Other Related Party Transactions
	A current board member and business partner in North Dakota has an interest in several entities with which the Partnership does business including the following:
		●	SBG Disposal, LLC (“SBG Disposal”) – Prior to the acquisition of certain assets and management fee contracts by CES LLC effective October 1, 2013, SBG Disposal provided staffing, management and back office services for a portion of the Partnership’s SWD facilities.  SBG Disposal is a wholly owned subsidiary of SBG Energy and provided services totaling $1.8 million for the year ended December 31, 2013. These costs are included in costs of services on the Consolidated Statements of Operations.
		●	Rud Transportation, LLC (“Rud”) – Rud, a wholly owned subsidiary of SBG Energy is a trucking company customer of the Partnership that hauls produced and flowback water to our facilities.  Total revenue recognized by the Partnership from Rud was $2.1 million, $1.8 million and $0.7 million for the years ended December 31, 2014, 2013 and 2012 (Predecessor), respectively.  Accounts receivable from Rud was $0.3 million and $0.4 million at December 31, 2014 and 2013, respectively, and is included in trade accounts receivable, net on the Consolidated Balance Sheets.
	Effective October 1, 2013, the Partnership provides management services to its 25% owned investee company, Alati Arnegard, LLC (“Arnegard”).  Management fee revenue earned from Arnegard totaled $0.6 million and $0.2 million for the years ended December 31, 2014 and 2013, respectively.  Accounts receivable from Arnegard totaled $0.1 million at December 31, 2014 and 2013 and is included in trade   accounts receivable, net on the Consolidated Balance Sheets.
	Effective October 1, 2013, the Partnership began outsourcing staffing and payroll services to an affiliated entity, Cypress Energy Management – Bakken Operations, LLC (“CEM-BO”).  Total employee related costs paid to CEM-BO were $3.2 million and $0.8 million for the years ended December 31, 2014 and 2013, respectively.  Included in accounts payable on the Consolidated Balance Sheets was $0.2 million and $0.1 million at December 31, 2014 and 2013, respectively, related to this arrangement.
	During 2013, PI&IS had business activity with Contract Pro, a nonaffiliated Canadian company owned by two former TIR-Foley employees.  Contract Pro offers employment services to specific individuals that could not otherwise be employed or placed by TIR-Foley.  TIR-Foley invoiced customers for the services of the Contract Pro employees and made the associated payments to Contract Pro, while keeping a portion of the proceeds.  In addition, Contract Pro reimbursed TIR-Foley for certain services, as the company shared TIR-Foley offices for a portion of the 2013 calendar year.  During 2013, Contract Pro separated their operations from TIR-Foley’s offices and the owners of Contract Pro resigned their employment positions with TIR-Foley.  The payments, net of Contract Pro reimbursements, made by TIR-Foley and TIR-Canada to Contract Pro during 2013 totaled $0.9 million.

Note_14_Commitments_and_Contin

Note 14 - Commitments and Contingencies	12 Months Ended
	Dec. 31, 2014
Commitments and Contingencies Disclosure [Abstract]
Commitments and Contingencies Disclosure [Text Block]	14	Commitments and Contingencies
	Security Deposits
	The Partnership has various performance obligations which are secured with short-term security deposits of $0.5 million and $0.4 million at December 31, 2014 and 2013, respectively.  These amounts are included in prepaid expenses and other on the Consolidated Balance Sheets.
	Employment Contract Commitments
	A subsidiary of the Partnership has employment agreements with certain of its executives.  The executive employment agreements are effective for a term of two-to-five years from the commencement date, after which time they will continue on an “at-will” basis.  These agreements provide for minimum annual compensation, adjusted for annual increases as authorized by the Board of Directors.  Certain agreements provide for severance payments in the event of specified termination of employment.  As of December 31, 2014, the aggregate commitment for future compensation and severance was approximately $0.9 million.
	Compliance Audit Contingencies
	Certain customer master service agreements (“MSA’s”) offer our customers the opportunity to perform periodic compliance audits, which include the examination of the accuracy of our invoices.  Should our invoices be determined to be inconsistent with the MSA, or inaccurate, the MSA’s may provide the customer the right to receive a credit or refund for any overcharges identified.  At December 30, 2014 and 2013, the Partnership had contingent liabilities of $0.2 million and $0.4 million respectively, associated with the probable settlement related to ongoing customer audits of various charges previously approved by customer representatives reflected in accrued payroll and other on the Consolidated Balance Sheets.  While the audits are ongoing, any contingent amounts that are still under evaluation will not be recorded as contingent liabilities until they are determined to be inconsistent with the MSA.
	Legal Proceedings
	On July 3, 2014, a group of former minority shareholders of TIR Inc., formerly an Oklahoma corporation, filed a civil action in the United States District Court for the Northern District of Oklahoma against TIR LLC, members of TIR LLC, and certain affiliates of TIR LLC’s members. TIR LLC is the successor in interest to TIR Inc., resulting from a merger between the entities that closed in December 2013 (the “TIR Merger”). The former shareholders in TIR Inc. claim that they did not receive sufficient value for their shares in the TIR Merger and are seeking rescission of the TIR Merger or, alternatively, compensatory and punitive damages. The Partnership is not named as a defendant in this civil action. TIR LLC and the other defendants have been advised by counsel that the action lacks merit. We believe that the possibility of the Partnership incurring material losses as a result of this action is remote. In addition, the Partnership anticipates no disruption in its business operations related to this action.
	On February 2, 2015, a former inspector for TIR LLC filed a putative collective action lawsuit alleging that TIR LLC failed to pay a class of workers overtime in compliance with the Fair Labor Standards Act (“FLSA”) titled Fenley v. TIR LLC in the United States District Court for the District of Kansas.  The plaintiff alleges he was a non-exempt employee of TIR and that he and other potential class members were not paid overtime in compliance with the FLSA. The plaintiff seeks to proceed as a collective action and to receive unpaid overtime and other monetary damages, including attorney’s fees. We believe that the possibility of the Partnership incurring material losses as a result of this action is remote.  In addition, we do not anticipate any disruption in our business operations related to this action.
	Leases
	The Partnership has entered into land lease agreements on four of its SWD facilities. The leases generally provide for initial terms of 15 - 20 years with renewal options. The Partnership also maintains various office leases in the U.S. and Canada, with its corporate offices in Tulsa, OK.  Lease expense under these operating leases was $0.1 million for the years ended December 31, 2014 and 2013.
	Minimum annual lease commitments under the current office lease and other operating leases at December 31, 2014 follows:
			(in thousands)
	2015		$	561
	2016			478
	2017			389
	2018			134
	2019			25
	Thereafter			557
	Total		$	2,144

Note_15_Segment_Disclosures

Note 15 - Segment Disclosures	12 Months Ended
	Dec. 31, 2014
Segment Reporting [Abstract]
Segment Reporting Disclosure [Text Block]	15	Segment Disclosures
	The Partnership’s operations consist of two reportable segments. We have recast segment financial information to reflect the conveyance of the entities comprising our reportable segments to the Partnership at the closing of our IPO (see Note 3). Our reportable segments consist of the following.
	W&ES – This segment consists of ten SWD facilities.  We aggregate these facilities for reporting purposes as they have similar economic characteristics and have centralized management and processing.  This segment generates revenue primarily by treating produced water and flowback water and injecting it into our SWD facilities.  Segment results are driven primarily by the volumes of water we inject into the SWD facilities and the fees we charge for our services.  These fees are charged on a per barrel basis and vary based on the quantity and type of saltwater disposed, competitive dynamics and operating costs.  In addition, for minimal marginal cost, we generate revenue by selling residual oil recovered from the disposal process.
	PI&IS – This segment consists of the operations of the TIR Entities.  We aggregate these operating entities for reporting purposes as they have similar economic characteristics, as well as possessing centralized management and processing.  This segment provides independent inspection and integrity services to various energy, public utility and pipeline companies.  The inspectors in this segment perform a variety of inspection and integrity services on midstream pipelines, gathering systems and distribution systems, including data gathering and supervision of third-party construction, inspection, and maintenance and repair projects.  Our results in this segment are driven primarily by the number and type of inspectors performing services for customers and the fees charged for those services, which depend on the nature and duration of the project.  The financial results of this segment have been included since June 26, 2013, the date Holdings and its affiliates acquired a controlling interest in the TIR Entities.
	The following table outlines segment operating income and a reconciliation of total segment operating income to net income before income tax expense.
			W&ES			PI&IS		Other			Total
			(in thousands)
	Year ended December 31, 2014
	Revenue		$	22,416		$	382,002	$	-		$	404,418
	Costs of services			8,617			346,738		-			355,355
	Gross margin			13,799			35,264		-			49,063
	General and administrative expense			3,090			17,734		497			21,321
	Impairments			32,546			-		-			32,546
	Depreciation, amortization and accretion			3,806			2,539		-			6,345
	Operating (loss) income		$	(25,643	)	$	14,991	$	(497	)		(11,149	)
	Interest expense, net											3,208
	Offering costs											446
	Other expense, net											(92	)
	Net loss before income tax expense										$	(14,711	)
	Total Assets		$	50,296		$	136,224	$	3,322
	Year ended December 31, 2013
	Revenue		$	22,232		$	226,901	$	-		$	249,133
	Costs of services			7,347			206,343		-			213,690
	Gross margin			14,885			20,558		-			35,443
	General and administrative expense			3,292			9,175		-			12,467
	Impairments			3,429			702		-			4,131
	Depreciation, amortization and accretion			3,837			1,327		-			5,164
	Operating income		$	4,327		$	9,354	$	-			13,681
	Interest expense, net											4,000
	Offering costs											1,376
	Gain on reversal of contingent consideration											(11,250	)
	Other expense, net											(37	)
	Net income before income tax expense										$	19,592
	Total Assets		$	81,403		$	154,352	$	4,835
	Year ended December 31, 2012
	Revenue		$	619		$	-	$	-		$	619
	Costs of services			309			-		-			309
	Gross margin			310			-		-			310
	General and administrative expense			(4	)		-		2,060			2,056
	Depreciation, amortization and accretion			99			-		-			99
	Operating income (loss)		$	215		$	-	$	(2,060	)	$	(1,845	)
	Total Assets		$	79,990		$	-	$	-
	Year ended December 31, 2012 (Predecessor)
	Revenue		$	12,203		$	-	$	-		$	12,203
	Costs of services			3,662			-		-			3,662
	Gross margin			8,541			-		-			8,541
	General and administrative expense			477			-		-			477
	Depreciation, amortization and accretion			1,398			-		-			1,398
	Operating income		$	6,666		$	-	$	-			6,666
	Interest expense, net											111
	Other expense, net											(40	)
	Net income before income tax expense										$	6,595

Note_16_Distributions

Note 16 - Distributions	12 Months Ended
	Dec. 31, 2014
Distributions [Abstract]
Distributions [Text Block]	16	Distributions
	We paid the following distributions related to the year ended December 31, 2014 (in thousands, except per unit amount):
	Payment Date		Per Unit		Total
			Cash Distribution		Cash Distribution
	May 15, 2014 (a)		$	0.301389	$	3,565
	14-Aug-14			0.396844		4,693
	14-Nov-14			0.406413		4,806
				1.104646		13,064
	February 14, 2015 (b)			0.406413		4,806
			$	1.511059	$	17,870
	(a)	Distribution was pro-rated from the date of our IPO through March 31, 2015.
	(b)	Fourth quarter 2014 distribution was declared and paid in 2015.

Note_17_Subsequent_Events

Note 17 - Subsequent Events	12 Months Ended
	Dec. 31, 2014
Subsequent Events [Abstract]
Subsequent Events [Text Block]	17	Subsequent Events
	Additional Interest in the TIR Entities
	Subsequent to year-end effective February 1, 2015, the Partnership acquired the remaining 49.9% interest in the TIR Entities for $52.6 million financed through the Partnership’s acquisition revolving credit facility of the Credit Agreement and now owns 100% of the TIR Entities as of that date.  Since the Partnership already controlled and consolidated the TIR Entities, the entire $52.6 million will be recorded directly to owners’ equity.  No pro forma results of operations have been provided due to the fact that the Partnership has already consolidated the results of the TIR Entities, therefore the results of operations are already included in its Consolidated Financial Statements.
	Acquisition of Controlling Interest in Hydrostatic Testing Entity
	Effective May 1, 2015, the Partnership acquired a 51% controlling interest in Brown Integrity, LLC (“Brown”), a hydrostatic pipeline inspection and integrity services business for $10.7 million, financed through the Partnership’s Credit Agreement acquisition revolving credit and working capital revolving credit facilities.  In addition, provisions in the purchase agreement provide for certain earn-out payments that could increase the purchase price an additional $9.5 million dependent upon Brown’s distributable cash flows generated over the next two years. The Partnership also has the right, but not the obligation, to acquire the remaining 49% of Brown commencing May 1, 2017 pursuant to a formula that would yield a maximum purchase price of $28 million in any combination of cash and/or Partnership units (at the Partnership’s discretion). Due to the recent closing date of this transaction, an estimate of the effects this acquisition will have on the Condensed Consolidated Financial Statements has not yet been made. The Partnership is currently in the process of determining the fair values of the assets and liabilities acquired under the acquisition method of accounting as outlined in Note 2.
	Management Service Contracts
	The Partnership has historically provided management services for non-owned SWD facilities under contractual arrangements. In May 2015, the Partnership was notified by principals of two of our management services customers (under common ownership) that they were terminating our management contracts. While management of the Partnership believes that the parties do not have the right to terminate the agreements, the termination of these agreements would result in a reduction of management fee revenue and a corresponding reduction in labor costs associated with staffing the facilities. Management fee revenues related to these contracts totaled $0.3 million for the three months ended March 31, 2015.
	Credit Agreement Amendment
	On May 4, 2015, the Partnership and the Partnership’s lenders, entered into Amendment No. 2 to the Credit Agreement (the “Amendment”), which amends the Credit Agreement to, among other matters, (i) allow each of Tulsa Inspection Resources – Canada ULC and Foley Inspection Services ULC to join the Credit Agreement as an additional borrower under the Credit Agreement, and (ii) amend certain other provisions of the Credit Agreement as more specifically set forth in the Amendment.

Note_18_Condensed_Consolidatin

Note 18 - Condensed Consolidating Financial Statements	12 Months Ended
	Dec. 31, 2014
Disclosure Text Block Supplement [Abstract]
Condensed Financial Statements [Text Block]	18	Condensed Consolidating Financial Statements
	The following financial information reflects consolidating financial information of the Partnership and its wholly owned guarantor subsidiaries and non-guarantor subsidiaries. The 2014 financial information reflects activity for the guarantor subsidiaries and non-guarantor subsidiaries for the full year. As outlined in Note 2, the 2013 financial information reflects activity for the TIR Entities (guarantor and non-guarantor subsidiaries) as if the contribution of the TIR Entities had occurred as of June 26, 2013. Consolidating financial information for 2012 has not been presented as all the financial information for that year would be attributable to the guarantor subsidiaries. The information is presented in accordance with the requirements of Rule 3-10 under the SEC’s Regulation S-X. The financial information may not necessarily be indicative of financial position, results of operations or cash flows had the guarantor subsidiaries or non-guarantor subsidiaries operated as independent entities. The Partnership has not presented separate financial and narrative information for each of the guarantor subsidiaries or non-guarantor subsidiaries because it believes such financial and narrative information would not provide any additional information that would be material in evaluating the sufficiency of the guarantor subsidiaries and non-guarantor subsidiaries. The Partnership anticipates issuing debt securities that will be fully and unconditionally guaranteed by the guarantor subsidiaries. These debt securities will be jointly and severally guaranteed by the guarantor subsidiaries. There are no restrictions on the Partnership’s ability to obtain cash dividends or other distributions of funds from the guarantor subsidiaries.
	Condensed Consolidating Balance Sheets
	As of December 31, 2014
	(in thousands)
									Non-			Consolidation
			Parent			Guarantors			Guarantors			Adjustments			Consolidated
	ASSETS
	Current assets:
	Cash and cash equivalents		$	982		$	16,598		$	3,177		$	-		$	20,757
	Trade accounts receivable, net			-			49,569			4,514			(8	)		54,075
	Receivables from affiliates			22			8,809			-			(8,831	)		-
	Deferred tax assets			-			15			53			-			68
	Prepaid expenses and other			-			2,339			101			-			2,440
	Total current assets			1,004			77,330			7,845			(8,839	)		77,340
	Property and equipment:
	Property and equipment, at cost			-			27,769			109			-			27,878
	Less: Accumulated depreciation			-			3,485			53			-			3,538
	Total property and equipment, net			-			24,284			56			-			24,340
	Intangible assets, net			-			28,414			1,831			-			30,245
	Goodwill			-			53,915			1,630			-			55,545
	Investment in subsidiaries			98,965			-			-			(98,965	)		-
	Notes receivable - affiliates			-			3,903			-			(3,903	)		-
	Debt issuance costs, net			2,318			-			-			-			2,318
	Other assets			-			35			19			-			54
	Total assets		$	102,287		$	187,881		$	11,381		$	(111,707	)	$	189,842
	LIABILITIES AND OWNERS' EQUITY
	Current liabilities:
	Accounts payable		$	34		$	2,161		$	266		$	-		$	2,461
	Accounts payable - affiliates			-			586			8,839			(8,839	)		586
	Accrued payroll and other			6			7,605			139			-			7,750
	Income taxes payable			-			507			39			-			546
	Total current liabilities			40			10,859			9,283			(8,839	)		11,343
	Long-term debt			-			77,600			-			-			77,600
	Notes payable - affiliates			-			-			3,479			(3,479	)		-
	Deferred tax liabilities			-			-			438			-			438
	Asset retirement obligations			-			33			-			-			33
	Total liabilities			40			88,492			13,200			(12,318	)		89,414
	Commitment and contingencies - Note 10
	Owners' equity:
	Total partners' capital			75,764			98,380			(1,819	)		(98,470	)		73,855
	Non-controlling interests			26,483			1,009			-			(919	)		26,573
	Total owners' equity			102,247			99,389			(1,819	)		(99,389	)		100,428
	Total liabilities and owners' equity		$	102,287		$	187,881		$	11,381		$	(111,707	)	$	189,842
	Condensed Consolidating Balance Sheets
	As of December 31, 2013
	(in thousands)
									Non-			Consolidation
			Parent			Guarantors			Guarantors			Adjustments			Consolidated
	ASSETS
	Current assets:
	Cash and cash equivalents		$	-		$	24,606		$	2,084		$	-		$	26,690
	Trade accounts receivable, net			-			53,684			7,046			-			60,730
	Receivables from affiliates			-			8,045			-			(8,045	)		-
	Deferred tax assets			-			-			134			-			134
	Deferred offering costs			2,539			-			-			-			2,539
	Prepaid expenses and other			147			1,281			30			-			1,458
	Total current assets			2,686			87,616			9,294			(8,045	)		91,551
	Property and equipment:
	Property and equipment, at cost			-			42,442			87			-			42,529
	Less: Accumulated depreciation			-			3,690			21			-			3,711
	Total property and equipment, net			-			38,752			66			-			38,818
	Intangible assets, net			-			30,373			2,178			-			32,551
	Goodwill			-			73,687			1,779			-			75,466
Notes receivable - affiliates			-			3,903			-			(3,903	)		-
Debt issuance costs, net			2,149			-			-			-			2,149
Other assets			-			48			6			1			55
Total assets		$	4,835		$	234,379		$	13,323		$	(11,947	)	$	240,590
LIABILITIES, PARENT NET INVESTMENT AND OWNERS' EQUITY
Current liabilities:
Accounts payable		$	-		$	1,708		$	965		$	-		$	2,673
Accounts payable - affiliates			-			-			8,044			(8,044	)		-
Accrued payroll and other			19			10,544			99			-			10,662
Income taxes payable			-			14,988			1,170			-			16,158
Total current liabilities			19			27,240			10,278			(8,044	)		29,493
Long-term debt			-			75,000			-			-			75,000
Notes payable - affiliates			-			-			3,795			(3,795	)		-
Deferred tax liabilities			-			-			541			-			541
Asset retirement obligations			-			9			-			-			9
Total liabilities			19			102,249			14,614			(11,839	)		105,043
Commitments and contingencies - Note 10
Total parent net investment and owners' equity			4,816			132,130			(1,291	)		(108	)		135,547
Total liabilities, parent net investment and owners' equity		$	4,835		$	234,379		$	13,323		$	(11,947	)	$	240,590
Condensed Consolidating Statements of Operations
For the Year Ended December 31, 2014
(in thousands)
								Non-			Consolidation
		Parent			Guarantors			Guarantors			Adjustments			Consolidated
Revenues		$	-		$	370,081		$	34,337		$	-		$	404,418
Costs of services			-			323,821			31,534			-			355,355
Gross margin			-			46,260			2,803			-			49,063
Operating costs and expense:
General and administrative			-			19,257			2,064			-			21,321
Depreciation, amortization and accretion			-			6,136			209			-			6,345
Impairments			-			32,546			-			-			32,546
Operating income			-			(11,679	)		530			-			(11,149	)
Other income (expense):
Equity earnings (loss) in subsidiaries			(14,134	)		-			-			14,134			-
Interest expense, net			(983	)		(1,892	)		(333	)		-			(3,208	)
Offering costs			(446	)		-			-			-			(446	)
Other, net			-			84			8			-			92
Net income before income tax expense			(15,563	)		(13,487	)		205			14,134			(14,711	)
Income tax expense			-			356			112			-			468
Net income			(15,563	)		(13,843	)		93			14,134			(15,179	)
Net income attributable to non-controlling interests			4,646			291			-			36			4,973
Net income attributable to controlling interests		$	(20,209	)	$	(14,134	)	$	93		$	14,098		$	(20,152	)
Condensed Consolidating Statements of Operations
For the Year Ended December 31, 2013
Non-Guarantors for the Period June 26, 2013 through December 31, 2013
(in thousands)
								Non-			Consolidation
		Parent			Guarantors			Guarantors			Adjustments			Consolidated
Revenues		$	-		$	222,250		$	26,883		$	-		$	249,133
Costs of services			-			188,928			24,762			-			213,690
Gross margin			-			33,322			2,121			-			35,443
Operating costs and expense:
General and administrative			-			11,283			1,184			-			12,467
Depreciation, amortization and accretion			-			5,027			137			-			5,164
Impairments			-			3,429			702			-			4,131
Operating income			-			13,583			98			-			13,681
Other income (expense):
Equity earnings (loss) in subsidiaries			-			-			-			-			-
Interest expense, net			(18	)		(3,822	)		(160	)		-			(4,000	)
Offering costs			(1,376	)		-			-			-			(1,376	)
Gain on reversal of contingent consideration			-			11,250			-			-			11,250
Other, net			-			41			(4	)		-			37
Net income (loss) before income tax expense			(1,394	)		21,052			(66	)		-			19,592
Income tax expense			-			14,187			1,050			-			15,237
Net income (loss)			(1,394	)		6,865			(1,116	)		-			4,355
Net income attributable to non-controlling interests			-			22			-			-			22
Net income (loss) attributable to controlling interests		$	(1,394	)	$	6,843		$	(1,116	)	$	-		$	4,333
Condensed Consolidating Statements of Comprehensive Income (Loss)
For the Year Ended December 31, 2014
(in thousands)
								Non-			Consolidation
		Parent			Guarantors			Guarantors			Adjustments			Consolidated
Net income (loss)		$	(15,563	)	$	(13,843	)	$	93		$	14,134		$	(15,179	)
Other comprehensive (loss):
Foreign currency translation			-			-			(621	)		(316	)		(937	)
Comprehensive income (loss)		$	(15,563	)	$	(13,843	)	$	(528	)	$	13,818		$	(16,116	)
Comprehensive income (loss) attributable to non-controlling interests			4,646			291			-			(279	)		4,658
Comprehensive income (loss) attributable to controlling interests		$	(20,209	)	$	(14,134	)	$	(528	)	$	14,097		$	(20,774	)
Condensed Consolidating Statements of Comprehensive Income (Loss)
For the Year Ended December 31, 2013
Non-Guarantors for the Period June 26, 2013 through December 31, 2013
(in thousands)
								Non-			Consolidation
		Parent			Guarantors			Guarantors			Adjustments			Consolidated
Net income (loss)		$	(1,394	)	$	6,865		$	(1,116	)	$	-		$	4,355
Other comprehensive (loss):
Foreign currency translation			-			-			(112	)		-			(112	)
Comprehensive income (loss)		$	(1,394	)	$	6,865		$	(1,228	)	$	-		$	4,243
Comprehensive income attributable to non-controlling interests			-			22			-			-			22
Comprehensive income (loss) attributable to controlling interests		$	(1,394	)	$	6,843		$	(1,228	)	$	-		$	4,221
Condensed Consolidating Statements of Cash Flows
For the Year Ended December 31, 2014
(in thousands)
								Non-			Consolidation
		Parent			Guarantors			Guarantors			Adjustments			Consolidated
Operating activities:
Net income (loss)		$	(15,563	)	$	(13,843	)	$	93		$	14,134		$	(15,179	)
Adjustments to reconcile net income (loss) to cash provided by (used in) operating activities:
Depreciation, amortization and accretion			-			6,337			176			-			6,513
Impairments			-			32,546			-			-			32,546
Loss on asset disposal			-			3			-			-			3
Interest expense from debt issuance cost amortization			714			-			-			-			714
Amortization of equity-based compensation			785			-			-			-			785
Equity earnings in investee company			-			(46	)		-			-			(46	)
Distributions from investee company			-			55			-			-			55
Equity earnings in subsidiaries			14,134			-			-			(14,134	)		-
Deferred tax benefit, net			-			(15	)		2			-			(13	)
Non-cash allocated GP expenses			-			497			-			-			497
Changes in assets and liabilities:
Trade accounts receivable			(22	)		4,145			2,527			-			6,650
Prepaid expenses and other			744			(1,600	)		(77	)		-			(933	)
Accounts payable and accrued payroll and other			21			(3,121	)		136			-			(2,964	)
Income taxes payable			-			(14,481	)		(1,131	)		-			(15,612	)
Net cash provided by operating activities			813			10,477			1,726			-			13,016
Investing activities:
Acquisition of business			-			(1,769	)		-			-			(1,769	)
Purchase of property and equipment			-			(517	)		-			-			(517	)
Net cash used in investing activities			-			(2,286	)		-			-			(2,286	)
Financing activities:
Proceeds from initial public offering			80,213			-			-			-			80,213
Distribution of initial public offering proceeds to Cypress Energy Holdings, LLC			(80,213	)		-			-			-			(80,213	)
Payment of deferred offering costs			(314	)		-			-			-			(314	)
Advances on long-term debt			-			7,600			-			-			7,600
Repayment of long-term debt			-			(5,000	)		-			-			(5,000	)
Debt issuance costs			(883	)		-			-			-			(883	)
Contributions from general partner			-			(168	)		-			-			(168	)
Net advances from members			(105	)		587			-			-			482
Distributions from subsidiaries			14,535			(14,535	)		-			-			-
Distributions to limited partners			(13,064	)		-			-			-			(13,064	)
Distributions to non-controlling members of the TIR Entities			-			(4,683	)		-			-			(4,683	)
Net cash provided by (used in) financing activities			169			(16,199	)		-			-			(16,030	)
Effects of exchange rates on cash			-			-			(633	)		-			(633	)
Net increase (decrease) in cash and cash equivalents			982			(8,008	)		1,093			-			(5,933	)
Cash and cash equivalents, beginning of period			-			24,606			2,084			-			26,690
Cash and cash equivalents, end of period		$	982		$	16,598		$	3,177		$	-		$	20,757
Non-cash items:
Accounts payable excluded from capital expenditures		$	-		$	756		$	-		$	-		$	756
Supplemental cash flow disclosures:
Cash taxes paid			-			16,420			254			-		$	16,674
Cash interest paid			-			2,415			-			-			2,415
Condensed Consolidating Statements of Cash Flows
For the Year Ended December 31, 2013
Non-Guarantors for the Period June 26, 2013 through December 31, 2013
(in thousands)
								Non-			Consolidation
		Parent			Guarantors			Guarantors			Adjustments			Consolidated
Operating activities:
Net income (loss)		$	(1,394	)	$	6,865		$	(1,116	)	$	-		$	4,355
Adjustments to reconcile net income (loss) to net cash provided by (used in) operating activities:
Depreciation, amortization and accretion			-			5,124			137			-			5,261
Impairments			-			3,429			702			-			4,131
Gain on reversal of contingent consideration			-			(11,250	)		-			-			(11,250	)
Interest expense from debt issuance cost amortization			-			1,219			-			-			1,219
Equity earnings in investee company			-			(32	)		-			-			(32	)
Deferred tax benefit, net			-			(1,751	)		(265	)		-			(2,016	)
Stock option expense			-			90			-			-			90
Changes in assets and liabilities:
Trade accounts receivable			-			(10,705	)		1,912			-			(8,793	)
Prepaid expenses and other			(147	)		395			35			-			283
Accounts payable and accrued payroll and other			19			(2,843	)		914			-			(1,910	)
Income taxes payable			-			14,417			1,399			-			15,816
Net cash provided by (used in) operating activities			(1,522	)		4,958			3,718			-			7,154
Investing activities:
Cash acquired - TIR Entities			-			6,628			3,480			-			10,108
Acquisition of business			-			(500	)		-			-			(500	)
Purchase of property and equipment			-			(3,829	)		-			-			(3,829	)
Net cash provided by investing activities			-			2,299			3,480			-			5,779
Payment of deferred offering costs			(2,539	)		-			-			-			(2,539	)
Advances on long-term debt			-			75,000			-			-			75,000
Repayment of long-term debt			-			(14,361	)		(5,024	)		-			(19,385	)
Net payments on factoring agreement			-			(36,748	)		-			-			(36,748	)
Payment of debt issuance costs			(2,149	)		(1,219	)		-			-			(3,368	)
Payments on behalf of affiliates			-			(5,763	)		-			-			(5,763	)
Purchase of non-controlling interests			-			(572	)		-			-			(572	)
Tax benefit of stock options exercised			-			528			-			-			528
Contributions from general partner			6,210			-			-			-			6,210
Net cash provided by (used in) financing activities			1,522			16,865			(5,024	)		-			13,363
Effect of exchange rates on cash			-			-			(90	)		-			(90	)
Net increase in cash and cash equivalents			-			24,122			2,084			-			26,206
Cash and cash equivalents, beginning of period			-			484			-			-			484
Cash and cash equivalents, end of period		$	-		$	24,606		$	2,084		$	-		$	26,690
Non-cash items:
Accounts payable excluded from capital expenditures		$	-		$	330		$	-		$	-		$	330
Supplemental cash flow disclosures:
Cash taxes paid		$	-		$	717		$	100		$	-		$	817
Cash interest paid			-			3,917			-			-			3,917

Quarterly_Financial_Informatio

Quarterly Financial Information (unaudited)	12 Months Ended
	Dec. 31, 2014
Quarterly Financial Information Disclosure [Abstract]
Quarterly Financial Information [Text Block]	CYPRESS ENERGY PARTNERS, L.P.
	Quarterly Financial Information
	(Unaudited)
	The following table sets forth certain unaudited financial data for each quarter during 2014 and 2013.  The unaudited quarterly information includes all normal recurring adjustments that we consider necessary for a fair presentation of the information shown.
	2014	Quarter Ended,
		( in thousands, except per unit amounts )
		March 31,		June 30,		September 30,		December 31,
	Revenues	$	97,523	$	93,722	$	111,016	$	102,157
	Gross margin		11,420		12,303		13,281		12,059
	Impairments		-		-		-		32,546
	Net income (loss)		3,517		4,929		5,097		(28,722	)
	Net income (loss) attributable to partners		2,744		3,680		3,555		(30,131	)
	Net income (loss) per common limited partner unit – basic		0.18		0.31		0.3		(2.51	)
	Net income (loss) per common limited partner unit – diluted		0.17		0.31		0.3		(2.51	)
	Net income (loss) per subordinated limited partner unit –basic and diluted		0.18		0.31		0.3		(2.51	)
	2013	Quarter Ended,
		( in thousands )
		March 31,		June 30,		September 30,		December 31,
	Revenues	$	5,337	$	9,176	$	116,980	$	117,640
	Gross margin		3,755		3,725		14,311		13,652
	Impairments		-		-		-		4,131
	Gain on reversal of contingent consideration		-		11,250		-		-
	Income tax expense		-		53		1,211		13,973
	Net income		2,231		12,824		4,488		(15,188	)
	Net income attributable to controlling interests		2,231		12,824		4,488		(15,210	)

Accounting_Policies_by_Policy_

Accounting Policies, by Policy (Policies)	12 Months Ended
	Dec. 31, 2014
Accounting Policies [Abstract]
Basis of Accounting, Policy [Policy Text Block]	Basis of Presentation
	The financial information for periods prior to the IPO have been recast to reflect the conveyance of the Contributed Entities to the Partnership at the closing of our IPO, as if the contribution of CEP LLC had occurred as of March 15, 2012, the inception date of CEP LLC, and the contribution of the TIR Entities had occurred as of June 26, 2013, as Holdings and its affiliates did not acquire a controlling interest in the TIR Entities until June 26, 2013.  All significant intercompany transactions and account balances have been eliminated.  We have made certain reclassifications to the prior period financial statements to conform with classification methods used in the current fiscal year.  These reclassifications had no impact on previously reported amounts of total assets, total liabilities, owners’ equity, or net income.
	The information presented for our Predecessor for 2012 includes the activity of the four subsidiaries contributed to Holdings prior to the contribution of CEP LLC to the Partnership and does not reflect the fair value of the assets and liabilities recorded by the Partnership when the Predecessor was acquired by CEP LLC (see Note 4).
	The accompanying Consolidated Financial Statements have been prepared in accordance with accounting principles generally accepted in the United States (“GAAP”) for consolidated financial information and in accordance with the rules and regulations of the Securities and Exchange Commission.  The Consolidated Financial Statements include all adjustments considered necessary for a fair presentation of the financial position and results of operations for the periods presented.  Such adjustments consist only of normal recurring items, unless otherwise disclosed herein.
Consolidation, Policy [Policy Text Block]	Principles of Consolidation
	The Consolidated Financial Statements include the accounts of the Partnership.  All intercompany accounts and transactions have been eliminated in consolidation.
Use of Estimates, Policy [Policy Text Block]	Use of Estimates in the Preparation of Financial Statements
	The preparation of the Partnership’s Consolidated Financial Statements in conformity with GAAP requires management to make estimates and assumptions that affect the amounts reported in the Consolidated Financial Statements and accompanying notes.  Actual results could differ from those estimates.
	Areas requiring the use of assumptions, judgments, and estimates include amounts of expected future cash flows used in determining possible impairments of goodwill, intangible assets, property and equipment, the determination of fair values associated with the allocation of purchase price in business combinations, and future asset retirement obligations.  Certain estimates are inherently imprecise and may change as future information becomes available.  Judgments and assumptions used in the Partnership’s estimate of future cash flows and an asset’s fair value include such matters as the estimation of oil and gas drilling and producing volumes in the markets served, risks associated with the different geological formation zones into which salt water is disposed, expected future disposal rates and commodity prices, capital expenditures, operating costs and appropriate discount rates.  The use of alternative judgments and/or assumptions could result in different outcomes.
Fair Value Measurement, Policy [Policy Text Block]	Fair Value Measurement
	The Partnership utilizes fair value measurements to measure assets in a business combination or assess impairment of property and equipment, intangible assets and goodwill. Fair value is the amount received from the sale of an asset or the amount paid to transfer a liability in an orderly transaction between market participants (an exit price) at the measurement date. Fair value is a market-based measurement considered from the perspective of a market participant. The Partnership uses market data or assumptions that it believes market participants would use in pricing the asset or liability, including assumptions about risk and the risks inherent in the inputs to the valuation.  These inputs can be readily observable, market corroborated, or unobservable.  The Partnership applies both market and income approaches for fair value measurements using the best available information while utilizing valuation techniques that maximize the use of observable inputs and minimize the use of unobservable inputs.
	The fair value hierarchy prioritizes the inputs used to measure fair value, giving the highest priority to quoted prices in active markets for identical assets or liabilities (Level 1 measurement) and the lowest priority to unobservable inputs (Level 3 measurement).  The Partnership classifies fair value balances based on the observability of those inputs.  The three levels of the fair value hierarchy are as follows:
		•	Level 1 – Quoted prices for identical assets or liabilities in active markets that management has the ability to access.  Active markets are those in which transactions for the asset or liability occur in sufficient frequency and volume to provide pricing information on an ongoing basis.
		•	Level 2 – Inputs are other than quoted prices in active markets included in Level 1 that are either directly or indirectly observable.  These inputs are either directly observable in the marketplace or indirectly observable through corroboration with market data for substantially the full contractual term of the asset or liability being measured.
		•	Level 3 – Inputs that are not observable for which there is little, if any, market activity for the asset or liability being measured.  These inputs reflect management’s best estimate of the assumptions market participants would use in determining fair value.
Contributions From General Partner [Policy Text Block]	Contributions from General Partner
	During 2013, entities affiliated with Cypress Energy Partners, GP, LLC, (“General Partner”) incurred $6.2 million of costs associated with our initial public offering and our credit agreement.  These costs were transferred to the Partnership as offering costs, deferred offering costs and/or debt issuance costs and have been recorded as contributions to the Partnership.
	During 2014, Holdings incurred allocated overhead expenses on behalf of the Partnership totaling $0.5 million. These costs represent amounts incurred by Holdings in excess of amounts charged under our amended and restated omnibus agreement.  These expenses are reflected as general and administrative in the Consolidated Statement of Operations for the year ended December 31, 2014 and as an equity contribution in the Consolidated Statement of Owners’ Equity.
Cash and Cash Equivalents, Policy [Policy Text Block]	Cash and Cash Equivalents
	The Partnership considers all investments purchased with initial maturities of three months or less to be cash equivalents.  Cash equivalents consist primarily of investments in highly liquid securities.  The carrying amounts of cash and cash equivalents reported in the balance sheet approximate fair value.
	U.S. cash balances at December 31, 2014, are insured by the Federal Deposit Insurance Corporation (FDIC) up to $250 thousand per financial institution.  Canadian cash balances are insured by the Canada Deposit Insurance Corporation (CDIC) up to $100 thousand per financial institution.  At times, cash balances may be in excess of the FDIC or CDIC insurance limits.  We periodically assess the financial condition of the institutions where we deposit funds and for the years ended December 31, 2014 and 2013, we believe our credit risk related to these funds is minimal.
Offering Costs [Policy Text Block]	Deferred Offering Costs
	Incremental costs directly attributable to an offering of equity securities are deferred and charged against the gross proceeds of the offering as a reduction in owners’ equity, including underwriter fees, legal and accounting fees associated with the preparation of the registration statement, and other costs related to the promotion of the offering.  All other costs that are not directly related to the offering are expensed as incurred.
Property, Plant and Equipment, Policy [Policy Text Block]	Property and Equipment
	Property and equipment consist of land, land improvements, buildings, facilities, wells and equipment, computer and office equipment, and vehicles.  The Partnership records property and equipment at cost.  Costs of renewals and improvements that substantially extend the useful lives of the assets are capitalized.  Maintenance and repairs are expensed as incurred.  Depreciation for these assets is computed using the straight-line method over estimated useful lives.  Upon retirement, impairment or disposition of assets, the costs and related accumulated depreciation are removed from the accounts with the resulting gain or losses, if any, reflected in the Consolidated Statements of Operations.
Debt Issuance Costs [Policy Text Block]	Debt Issuance Costs
	Debt issuance costs represent fees and expenses associated with securing the Partnership’s credit agreement (see Note 8).  Amortization of the capitalized debt issuance costs is computed using the effective interest method over the remaining estimated life of the credit agreement.
Income Tax, Policy [Policy Text Block]	Income Taxes
	As a limited partnership, we generally are not subject to federal, state or local income taxes.  The tax on the net income of the Partnership is generally borne by the individual partners.  Net income for financial statement purposes may differ significantly from taxable income of the partners as a result of differences between the tax basis and financial reporting basis of assets and liabilities and the taxable income allocation requirements under our partnership agreement.  The aggregated difference in the basis of our net assets for financial and tax reporting purposes cannot be readily determined because information regarding each partners’ tax attributes in us is not available to us.
	On December 9, 2013, the TIR Entities converted from corporate status to pass-through entities for U.S. federal income tax purposes.  The Partnership recorded tax expense of $15.0 million for income taxes associated with the gain on this conversion in the year ended December 31, 2013.  The TIR Entities that have Canadian activity remain taxable in Canada.  In addition, the Partnership has one subsidiary, Tulsa Inspection Resources – PUC, LLC (“TIR-PUC”), which has elected to be taxed as a corporation for U.S. federal income tax purposes.  The amounts recognized as income tax expense, income taxes payable, deferred tax assets and deferred tax liabilities on the Consolidated Financial Statements represent the Canadian and U.S. taxes referred to above, as well as partnership-level taxes levied by various states, primarily composed of franchise taxes assessed by the state of Texas.
	As a publicly traded limited partnership, we are subject to a statutory requirement that our "qualifying income" (as defined by the Internal Revenue Code, related Treasury Regulations, and Internal Revenue Service pronouncements) exceed 90% of our total gross income, determined on a calendar year basis. If our qualifying income does not meet this statutory requirement, we could be taxed as a corporation for federal and state income tax purposes. For the year ended December 31, 2014, the year we became a publicly traded limited partnership, our qualifying income met the statutory requirement.
	The Partnership evaluates uncertain tax positions for recognition and measurement in the Consolidated Financial Statements.  To recognize a tax position, the Partnership determines whether it is more likely than not that a tax position will be sustained upon examination, including resolution of any related appeals or litigation, based on the technical merits of the position.  A tax position that meets the more likely than not threshold is measured to determine the amount of benefit to be recognized in the Consolidated Financial Statements.  The amount of tax benefit recognized with respect to any tax position is measured as the largest amount of benefit that is greater than 50% likely of being realized upon settlement.  The Partnership had no uncertain tax positions that required recognition in the financial statements at December 31, 2014 or 2013.  Any interest or penalties would be recognized as a component of income tax expense.
Revenue Recognition, Policy [Policy Text Block]	Revenue Recognition
	Revenues are recognized when there is persuasive evidence that an arrangement exists, delivery has occurred or services have been rendered, the price is fixed or determinable and collectability is reasonably assured.  Water disposal revenues are recognized upon receipt of the wastewater at our disposal facilities.  Oil disposal revenues are recognized when delivered to the customer and collectability is reasonably assured.
	Revenues related to pipeline inspection services are recognized when the services are provided and collectability is reasonably assured.  Generally, inspection services and use of provided equipment are billed on a per day basis.
Share-based Compensation, Option and Incentive Plans Policy [Policy Text Block]	Unit-Based Compensation
	Our General Partner adopted a long-term incentive plan (“LTIP”) in connection with the IPO.  The cost of employee services received in exchange for equity instruments is measured based on the grant-date fair value of those instruments.  That cost is recognized straight-line over the requisite service period (often the vesting period) as discussed in Note 12.
Earnings Per Share, Policy [Policy Text Block]	Net Income Per Unit
	We calculate basic net income per limited partner unit for each period by dividing net income by the weighted-average number of limited partner units outstanding. Diluted net income per limited partner unit for each period is the same calculation as basic net income per limited partner unit, except the weighted-average limited partner units outstanding includes the dilutive effect of phantom unit grants associated with our long-term incentive plan.
	The Company had a net loss for the year ended December 31, 2014.  As a result, all phantom restricted units were anti-dilutive and excluded from the weighted average units used in determining the loss per unit. There were 14,520 phantom restricted units that were excluded from the calculation of net income per unit as they were anti-dilutive.
Accounts Receivable and Concentration of Credit Risk [Policy Text Block]	Accounts Receivable and Concentration of Credit Risk
	We operate in the United States and Canada.  We grant unsecured credit to customers under normal industry standards and terms, and have established policies and procedures that allow for an evaluation of each customer’s creditworthiness as well as general economic conditions.  The Partnership determines accounts receivable allowances based on management’s assessment of the creditworthiness of the customers and other collection actions.  Trade receivables are written off against the allowance when deemed uncollectible.  Recoveries of trade receivables previously written off are recorded when received.  The Partnership does not typically charge interest on past due trade receivables and does not require collateral for its trade receivables.  The Partnership had an allowance for doubtful accounts of $0.2 million at December 31, 2014 and 2013, and recorded bad debt expense of $0.1 million and $0.4 million for the years ended December 31, 2014 and 2013, respectively.  There was no bad debt expense recorded during the year ended December 31, 2012.
	We had two customers that each represented more than 10% of total accounts receivable as of December 31, 2014.  If one or more of these customers were to default on their payment obligations, we may not be able to replace any of these customers in a timely fashion, on favorable terms, or at all.
Fair Value of Financial Instruments, Policy [Policy Text Block]	Fair Value of Financial Instruments
	The carrying amounts reported in the Consolidated Balance Sheets for cash and cash equivalents, trade accounts receivable, accounts payable, accounts payable – affiliates, accrued payroll and other and income taxes payable approximate their fair values.
	Assets and Liabilities Measured at Fair Value on a Nonrecurring Basis
	Certain assets and liabilities are reported at fair value on a nonrecurring basis in the Partnership’s Consolidated Balance Sheets. The following methods and assumptions were used to estimate the fair values:
Impairment or Disposal of Long-Lived Assets, Policy [Policy Text Block]	Impairments of Property and Equipment
	The Partnership reviews its property and equipment and intangible assets for impairment whenever events or changes in circumstances indicate, in the judgment of management, that a decline in the recoverability of their carrying value may have occurred.  When an indicator of impairment has occurred, the Partnership compares its estimate of undiscounted cash flows attributable to the assets to the carrying value of the assets to determine whether an impairment has occurred.  If the estimate of undiscounted cash flows is less than the carrying value of the asset group, the Partnership determines the amount of the impairment recognized in the financial statements by estimating the fair value of the assets using a discounted cash flow model and records a loss for the amount by which the carrying value exceeds the estimated fair value.  Assets are grouped for impairment purposes at each SWD facility, which includes the well and supporting well equipment and infrastructure, as this represents the lowest level of cash flows associated with the asset group.  The Partnership recorded impairment losses of $12.8 and $3.4 million for the years ended December 31, 2014 and 2013, respectively (see Note 5).
Goodwill and Intangible Assets, Goodwill, Policy [Policy Text Block]	Goodwill
	At December 31, 2014 and 2013, the Partnership had $55.6 and $75.5 million of goodwill, respectively.  Goodwill is not amortized, but, is subject to annual reviews on November 1 for impairment at a reporting unit level.  The reporting unit or units used to evaluate and measure goodwill for impairment are determined primarily from the manner in which the business is managed or operated.  A reporting unit is an operating segment or a component that is one level below an operating segment.  In accordance with ASC 350 “Intangibles — Goodwill and Other”, we have assessed the reporting unit definitions and determined that at December 31, 2014 and 2013, W&ES and PI&IS, are the appropriate reporting units for testing goodwill impairment.  The accounting estimate relative to assessing the impairment of goodwill is a critical accounting estimate for each of our reporting segments.
	For our PI&IS reporting unit, we performed a qualitative assessment to determine whether the fair value of the reporting unit was more likely than not less than its carrying value.  Our evaluation consisted of assessing various qualitative factors including current and projected future earnings, capitalization, current customer relationships and projects and the impact of lower crude oil prices on our earnings.  The qualitative assessment on this reporting unit indicated that there was no need to conduct further quantitative testing for goodwill impairment nor did our analysis indicate the reporting unit was at risk for a potential goodwill impairment.  Different judgments from those we used in our qualitative analysis could result in the requirement to perform a quantitative goodwill impairment analysis.
	For our W&ES segment, after giving consideration to certain qualitative factors including trends in the energy industry and recorded impairments of property and equipment, we elected to perform a quantitative goodwill impairment analysis.  We computed the fair value of the reporting unit employing multiple valuation methodologies, including a market approach (market price multiples of comparable companies) and an income approach (discounted cash flow analysis).  This approach is consistent with the requirement to utilize all appropriate valuation techniques as described in ASC 820-10-35-24 “Fair Value Measurements and Disclosures. ” Given recent declines in the price of crude oil and the related impact on the valuations of energy related companies, relevant market data was difficult to obtain and was of limited usefulness.  Accordingly, we relied heavily on the use of the income approach for the valuation of the reporting unit.
	As a result of our valuation we determined that the carrying value of the W&ES reporting unit exceed the fair value of the reporting unit resulting in a goodwill impairment charge of $19.8 million.  The W&ES segment has experienced increased competition in some of the regions in which we operate which has resulted in declining volumes and increased pricing pressure.  The fourth quarter decline in oil prices has intensified competitive pressures and had a direct impact on our revenues.  Many of our customers have announced significantly reduced drilling programs in the areas in which we operate.  The decline in drilling will directly impact the amount of flowback and produced water that we process and dispose.  The energy downturn is also expected to continue to negatively impact our pricing as our customers look for ways to reduce costs.  In addition, as we process lower water volumes, in particular flowback water volumes directly attributable to drilling, we will recover less skim oil.  Lower oil prices will also directly impact revenues as oil sales have historically represented in excess of 20% of our W&ES revenues.
Intangible Assets, Finite-Lived, Policy [Policy Text Block]	Intangible Assets
	Intangible assets represent acquired customer relationships, trade names, and certain other intangibles acquired via various acquisitions and have been recorded utilizing various assumptions to determine fair market value including, but not limited to, replacement costs, liquidation values, future cash flows on a discounted basis of the net assets acquired, pay-off values, and average royalty rates.  Due to the unobservable nature of these assumptions, these fair value measurements are considered to be Level 3 fair value estimates.  Amortization of intangible assets is computed utilizing the straight-line method over their estimated useful lives, typically 5 – 20 years.
	We review our other intangible assets for impairment whenever events or changes in circumstances indicate we should assess the recoverability of the carrying amount of the intangible asset. We recognized no impairments for other intangible assets in 2014 and 2012. During 2013, the Partnership determined that one of its trade names in PI&IS had been impaired and identified that the fair value of the trade name, using an undiscounted cash flow model, was less than its carrying amount.  A $0.7 million adjustment was made to reduce the carrying value of the trade name to its fair value.  The fair value was calculated using a discounted cash flow model applied to the expected royalty values generated from the use of the trade name.  Management estimates of the future royalties associated with the use of the trade name were based on forecasted total revenues.  Actual results could vary materially from these estimates, which could have a further impact on the fair value of the trade name.
Non-Controlling Interest [Policy Text Block]	Non-controlling Interest
	The Partnership holds a controlling interest in several entities which are not wholly owned.  The non-controlling interests shown in our Consolidated Balance Sheet at December 31, 2014 primarily includes the 49% membership interest in CES LLC that is owned by SBG Energy and the 49.9% interest in each of the TIR Entities that is owned by affiliates of Holdings.   Net income attributable to non-controlling interests shown in our Consolidated Statements of Operations reflects 49% of the net income of CES LLC for the years ended December 31, 2014 and 2013, and 49.9% of the net income of the TIR Entities for the period from our IPO through December 31, 2014.   The non-controlling interest in the TIR Entities is reduced by certain charges in accordance with our Partnership agreement.
Business Combinations Policy [Policy Text Block]	Business Combinations
	The Partnership evaluates all potential acquisitions and changes in control to determine whether it has purchased or acquired control of a business.  If the acquired or new controlled assets meet the definition of a business, it is accounted for as a business combination; otherwise it is accounted for as an asset acquisition.  Transactions discussed in Note 4 reflect business combinations for the periods described.
Foreign Currency Transactions and Translations Policy [Policy Text Block]	Foreign Currency Translation
	The reporting currency is the U.S. dollar.  Non-U.S. dollar denominated monetary items are translated into U.S. dollars at the rate of exchange in effect at the balance sheet date.  Non-U.S. dollar denominated non-monetary items are translated to U.S. dollars at the exchange rate in effect when the transactions occur.  Revenues and expenses denominated in foreign currencies are translated at the exchange rate in effect during the period.  Foreign exchange gains or losses on translation are included in other comprehensive income.
New Accounting Pronouncements, Policy [Policy Text Block]	New Accounting Standard
	The Financial Accounting Standards Board issued Accounting Standards Update (“ASU”) 2014-09 – Revenue from Contracts with Customers in May 2014.  ASU 2014-09 is intended to clarify the principles for recognizing revenue and develop a common standard for recognizing revenue for GAAP and International Financial Reporting Standards that is applicable to all organizations.  The Partnership will be required to comply with this ASU beginning in 2017.  We are currently evaluating the impact of this ASU on the Partnership.  We do not anticipate that the adoption of this ASU will materially impact our financial position, results of operations or cash flows.

Note_4_Business_Combinations_T

Note 4 - Business Combinations (Tables)	12 Months Ended
	Dec. 31, 2014
Note 4 - Business Combinations (Tables) [Line Items]
Business Acquisition, Pro Forma Information [Table Text Block]		2014			2013		2012
		( in thousands )
	Revenue as reported	$	404,418		$	249,133	$	619
	Business Combinations:
	SWD Facility		297			-		-
	TIR Entities Acquisition		-			152,989		233,803
	SBG Disposal Acquisition		-			814		-
	SBG Acquisition		-			-		8,588
	Moxie Acquisition		-			-		3,180
	Pro-forma revenue	$	404,715		$	402,936	$	246,190
	Net income (loss) as reported	$	(15,179	)	$	4,355	$	(1,845	)
	Business Combinations:
	SWD Facility		(213	)		-		-
	TIR Entities Acquisition		-			953		2,662
	SBG Disposal Acquisition		-			127		-
	SBG Acquisition		-			-		4,462
	Moxie Acquisition		-			-		1,391
	Pro-forma net income (loss)	$	(15,392	)	$	5,435	$	6,670
Salt Water Disposal Facility [Member]
Note 4 - Business Combinations (Tables) [Line Items]
Schedule of Recognized Identified Assets Acquired and Liabilities Assumed [Table Text Block]		Fair Value
		(in thousands)
	Current assets	$	50
	Property and equipment		1,837
	Intangible assets - contracts		241
	Total value of assets acquired		2,128
	Current liabilities assumed		386
	Asset retirement obligation		1
	Net assets acquired	$	1,741
Tulsa Inspection Resources Entities [Member]
Note 4 - Business Combinations (Tables) [Line Items]
Schedule of Recognized Identified Assets Acquired and Liabilities Assumed [Table Text Block]		Fair Value
		(in thousands)
	Cash	$	10,108
	Other working capital, net		33,990
	Property and equipment		1,075
	Intangible assets:
	Trade names and trademarks		10,850
	Inspector database		2,080
	Customer relationships		21,380
	Goodwill		40,638
	Total value of assets acquired		120,121
	Mezzanine debt		19,756
	Factoring debt		36,748
	Total liabilities assumed		56,504
	Net assets acquired	$	63,617
SBG Energy Services, LLC [Member]
Note 4 - Business Combinations (Tables) [Line Items]
Schedule of Recognized Identified Assets Acquired and Liabilities Assumed [Table Text Block]		Fair Value
		(in thousands)
	Current assets	$	35
	Property and equipment		300
	Intangible assets - customer relationships		150
	Goodwill		971
	Total assets acquired		1,456
	Current liabilities		35
	Net assets acquired	$	1,421
Moxie and SBG Acquisition [Member]
Note 4 - Business Combinations (Tables) [Line Items]
Schedule of Recognized Identified Assets Acquired and Liabilities Assumed [Table Text Block]		Moxie Acquisition			SBG Acquisition		Total
		( in thousands )
	Fair value of net assets:
	Current assets	$	288		$	2,947	$	3,235
	Property and equipment		16,634			30,017		46,651
	Related-party notes receivable		—			438		438
	Intangible assets		60			225		285
	Goodwill		6,903			26,974		33,877
	Total assets acquired		23,885			60,601		84,486
	Current liabilities		—			500		500
	Related-party notes payable		—			1,534		1,534
	Contingent consideration due sellers		—			11,250		11,250
	Asset retirement obligations		3			5		8
	Total liabilities assumed		3			13,289		13,292
	Total purchase price	$	23,882		$	47,312	$	71,194

Note_5_Property_and_Equipment_

Note 5 - Property and Equipment (Tables)	12 Months Ended
	Dec. 31, 2014
Property, Plant and Equipment [Abstract]
Property, Plant and Equipment [Table Text Block]					December 31,
	Asset Category	Useful Lives			2014			2013
					( in thousands )
	Land				$	2,049		$	2,049
	Land improvements	15 years				1,143			2,543
	Buildings and leasehold improvements	39 years				1,056			1,767
	Facilities, wells, and equipment	5 – 15 years				22,666			35,326
	Computer and office equipment	3 – 9 years				816			771
	Other	3 – 5 years				148			73
						27,878			42,529
	Less accumulated depreciation					(3,538	)		(3,711	)
	Net property and equipment				$	24,340		$	38,818
Details of Impairment of Long-Lived Assets Held and Used by Asset [Table Text Block]		Year Ended December 31,
		2014			2013
		(in thousands)
	Asset Category
	Land improvements	$	1,514		$	725
	Buildings and leasehold improvements		748			135
	Facilities, wells and equipment		14,796			2,964
			17,058			3,824
	Accumulated depreciation		(4,285	)		(397	)
	Impairment of facilities	$	12,773		$	3,427

Note_6_Goodwill_Tables

Note 6 - Goodwill (Tables)	12 Months Ended
	Dec. 31, 2014
Disclosure Text Block Supplement [Abstract]
Schedule of Goodwill [Table Text Block]		W&ES			PI&IS			Total
		(in thousands)
	Balance - December 31, 2012	$	33,877		$	-		$	33,877
	Goodwill from business combinations		971			40,638			41,609
	Foreign currency translation		-			(20	)		(20	)
	Balance - December 31, 2013		34,848			40,618			75,466
	Impairments		(19,773	)		-			(19,773	)
	Foreign currency translation		-			(148	)		(148	)
	Balance - December 31, 2014	$	15,075		$	40,470		$	55,545

Note_7_Intangible_Assets_Table

Note 7 - Intangible Assets (Tables)	12 Months Ended
	Dec. 31, 2014
Disclosure Text Block [Abstract]
Schedule of Finite-Lived Intangible Assets [Table Text Block]				31-Dec-14				31-Dec-13
		Useful		Gross		Accumulated		Gross		Accumulated
		Lives		Carrying		Amortization		Carrying		Amortization
				Amount				Amount
				( in thousands )
	Customer relationships	5-20 years		$	21,510	$	1,788	$	21,510	$	554
	Contracts	3 years			241		-		-		-
	Non-compete agreements	3 years			60		41		60		21
	Trademarks and trade names	10 years			10,135		1,638		10,135		553
	Inspector database	10 years			2,080		314		2,080		106
	Total			$	34,026	$	3,781	$	33,785	$	1,234
Schedule of Finite-Lived Intangible Assets, Future Amortization Expense [Table Text Block]	Year Ending December 31,	( in thousands )
	2015	$	2,468
	2016		2,391
	2017		2,391
	2018		2,305
	2019		2,281
	Thereafter		18,409
		$	30,245

Note_8_Credit_Agreement_Tables

Note 8 - Credit Agreement (Tables)	12 Months Ended
	Dec. 31, 2014
Debt Disclosure [Abstract]
Schedule of Long-term Debt Instruments [Table Text Block]		December 31,		Net borrowings		December 31,
		2013		or		2014
				repayments
		(in thousands)
	Acquisition revolving credit facility
	(3.26% at December 31, 2014)	$	25,000	$	2,600	$	27,600
	Borrowing base revolving credit facility
	(2.74% at December 31, 2014)		50,000		-		50,000
	Total long-term debt	$	75,000	$	2,600	$	77,600

Note_9_Income_Taxes_Tables

Note 9 - Income Taxes (Tables)	12 Months Ended
	Dec. 31, 2014
Income Tax Disclosure [Abstract]
Schedule of Components of Income Tax Expense (Benefit) [Table Text Block]		2014			2013
		(in thousands)
	Current expense:
	Federal	$	38		$	14,714
	State		332			2,462
	Canadian		100			285
	Total		470			17,461
	Deferred tax expense (benefit):
	Federal		(12	)		(1,553	)
	State		(3	)		(390	)
	Canadian		13			(281	)
	Total		(2	)		(2,224	)
	Total income tax expense	$	468		$	15,237
Schedule of Deferred Tax Assets and Liabilities [Table Text Block]		Year Ended December 31,
		2014			2013
		(in thousands)
	Current deferred tax assets:
	Accrued liabilities	$	17		$	1
	Bad debt reserve		-			28
	Canadian net operating loss		51			105
	Total	$	68		$	134
	Non-current deferred tax assets (liabilities):
	Property and equipment	$	2		$	3
	Intangible assets		(440	)		(544	)
	Total	$	(438	)	$	(541	)
Schedule of Effective Income Tax Rate Reconciliation [Table Text Block]		2014			2013			2012			Predecessor
											2012
					(in thousands)
	Tax (benefit) computed at statutory rate of 35%	$	(5,149	)	$	6,857		$	(646	)	$	2,170
	Income not subject to federal taxes		5,274			(4,793	)		646			(2,170	)
	State income taxes, net of federal benefit		326			535			-			-
	Tax on conversion of TIR, Inc. to pass through entities		-			12,892			-			-
	Other		17			(254	)		-			-
	Total income tax expense	$	468		$	15,237		$	-		$	-

Note_12_Equity_Compensation_Ta

Note 12 - Equity Compensation (Tables)	12 Months Ended
	Dec. 31, 2014
Disclosure of Compensation Related Costs, Share-based Payments [Abstract]
Schedule of Share-based Compensation, Activity [Table Text Block]		Number			Weighted
		of Units			Average
					Grant
					Date Fair
					Value / Unit
	Units at January 1, 2014		-		$	-
	Units granted		178,264			17.96
	Units forfeited		(19,911	)		(16.78	)
	Units at December 31, 2014		158,353			17.36
Schedule of Share-based Compensation, Stock Options, Activity [Table Text Block]		Quantity			Intrinsic Value
		( in shares )			( in thousands )
	Outstanding at June 26, 2013		7		$	2,450
	Granted		-			-
	Exercised		(5	)		(1,750	)
	Forfeited or expired		(2	)		(700	)
	Outstanding at December 31, 2013		-		$	-

Note_14_Commitments_and_Contin1

Note 14 - Commitments and Contingencies (Tables)	12 Months Ended
	Dec. 31, 2014
Commitments and Contingencies Disclosure [Abstract]
Schedule of Future Minimum Rental Payments for Operating Leases [Table Text Block]		(in thousands)
	2015	$	561
	2016		478
	2017		389
	2018		134
	2019		25
	Thereafter		557
	Total	$	2,144

Note_15_Segment_Disclosures_Ta

Note 15 - Segment Disclosures (Tables)	12 Months Ended
	Dec. 31, 2014
Segment Reporting [Abstract]
Schedule of Segment Reporting Information, by Segment [Table Text Block]		W&ES			PI&IS		Other			Total
		(in thousands)
	Year ended December 31, 2014
	Revenue	$	22,416		$	382,002	$	-		$	404,418
	Costs of services		8,617			346,738		-			355,355
	Gross margin		13,799			35,264		-			49,063
	General and administrative expense		3,090			17,734		497			21,321
	Impairments		32,546			-		-			32,546
	Depreciation, amortization and accretion		3,806			2,539		-			6,345
	Operating (loss) income	$	(25,643	)	$	14,991	$	(497	)		(11,149	)
	Interest expense, net										3,208
	Offering costs										446
	Other expense, net										(92	)
	Net loss before income tax expense									$	(14,711	)
	Total Assets	$	50,296		$	136,224	$	3,322
	Year ended December 31, 2013
	Revenue	$	22,232		$	226,901	$	-		$	249,133
	Costs of services		7,347			206,343		-			213,690
	Gross margin		14,885			20,558		-			35,443
	General and administrative expense		3,292			9,175		-			12,467
	Impairments		3,429			702		-			4,131
	Depreciation, amortization and accretion		3,837			1,327		-			5,164
	Operating income	$	4,327		$	9,354	$	-			13,681
	Interest expense, net										4,000
	Offering costs										1,376
	Gain on reversal of contingent consideration										(11,250	)
	Other expense, net										(37	)
	Net income before income tax expense									$	19,592
	Total Assets	$	81,403		$	154,352	$	4,835
	Year ended December 31, 2012
	Revenue	$	619		$	-	$	-		$	619
	Costs of services		309			-		-			309
	Gross margin		310			-		-			310
	General and administrative expense		(4	)		-		2,060			2,056
	Depreciation, amortization and accretion		99			-		-			99
	Operating income (loss)	$	215		$	-	$	(2,060	)	$	(1,845	)
	Total Assets	$	79,990		$	-	$	-
	Year ended December 31, 2012 (Predecessor)
	Revenue	$	12,203		$	-	$	-		$	12,203
	Costs of services		3,662			-		-			3,662
	Gross margin		8,541			-		-			8,541
	General and administrative expense		477			-		-			477
	Depreciation, amortization and accretion		1,398			-		-			1,398
	Operating income	$	6,666		$	-	$	-			6,666
	Interest expense, net										111
	Other expense, net										(40	)
	Net income before income tax expense									$	6,595

Note_16_Distributions_Tables

Note 16 - Distributions (Tables)	12 Months Ended
	Dec. 31, 2014
Distributions [Abstract]
Dividends Declared [Table Text Block]	Payment Date	Per Unit		Total
		Cash Distribution		Cash Distribution
	May 15, 2014 (a)	$	0.301389	$	3,565
	14-Aug-14		0.396844		4,693
	14-Nov-14		0.406413		4,806
			1.104646		13,064
	February 14, 2015 (b)		0.406413		4,806
		$	1.511059	$	17,870

Note_18_Condensed_Consolidatin1

Note 18 - Condensed Consolidating Financial Statements (Tables)	12 Months Ended
	Dec. 31, 2014
Disclosure Text Block Supplement [Abstract]
Condensed Balance Sheet [Table Text Block]								Non-			Consolidation
		Parent			Guarantors			Guarantors			Adjustments			Consolidated
	ASSETS
	Current assets:
	Cash and cash equivalents	$	982		$	16,598		$	3,177		$	-		$	20,757
	Trade accounts receivable, net		-			49,569			4,514			(8	)		54,075
	Receivables from affiliates		22			8,809			-			(8,831	)		-
	Deferred tax assets		-			15			53			-			68
	Prepaid expenses and other		-			2,339			101			-			2,440
	Total current assets		1,004			77,330			7,845			(8,839	)		77,340
	Property and equipment:
	Property and equipment, at cost		-			27,769			109			-			27,878
	Less: Accumulated depreciation		-			3,485			53			-			3,538
	Total property and equipment, net		-			24,284			56			-			24,340
	Intangible assets, net		-			28,414			1,831			-			30,245
	Goodwill		-			53,915			1,630			-			55,545
	Investment in subsidiaries		98,965			-			-			(98,965	)		-
	Notes receivable - affiliates		-			3,903			-			(3,903	)		-
	Debt issuance costs, net		2,318			-			-			-			2,318
	Other assets		-			35			19			-			54
	Total assets	$	102,287		$	187,881		$	11,381		$	(111,707	)	$	189,842
	LIABILITIES AND OWNERS' EQUITY
	Current liabilities:
	Accounts payable	$	34		$	2,161		$	266		$	-		$	2,461
	Accounts payable - affiliates		-			586			8,839			(8,839	)		586
	Accrued payroll and other		6			7,605			139			-			7,750
	Income taxes payable		-			507			39			-			546
	Total current liabilities		40			10,859			9,283			(8,839	)		11,343
	Long-term debt		-			77,600			-			-			77,600
	Notes payable - affiliates		-			-			3,479			(3,479	)		-
	Deferred tax liabilities		-			-			438			-			438
	Asset retirement obligations		-			33			-			-			33
	Total liabilities		40			88,492			13,200			(12,318	)		89,414
	Commitment and contingencies - Note 10
	Owners' equity:
	Total partners' capital		75,764			98,380			(1,819	)		(98,470	)		73,855
	Non-controlling interests		26,483			1,009			-			(919	)		26,573
	Total owners' equity		102,247			99,389			(1,819	)		(99,389	)		100,428
	Total liabilities and owners' equity	$	102,287		$	187,881		$	11,381		$	(111,707	)	$	189,842
								Non-			Consolidation
		Parent			Guarantors			Guarantors			Adjustments			Consolidated
	ASSETS
	Current assets:
	Cash and cash equivalents	$	-		$	24,606		$	2,084		$	-		$	26,690
	Trade accounts receivable, net		-			53,684			7,046			-			60,730
	Receivables from affiliates		-			8,045			-			(8,045	)		-
	Deferred tax assets		-			-			134			-			134
	Deferred offering costs		2,539			-			-			-			2,539
	Prepaid expenses and other		147			1,281			30			-			1,458
	Total current assets		2,686			87,616			9,294			(8,045	)		91,551
	Property and equipment:
	Property and equipment, at cost		-			42,442			87			-			42,529
	Less: Accumulated depreciation		-			3,690			21			-			3,711
	Total property and equipment, net		-			38,752			66			-			38,818
	Intangible assets, net		-			30,373			2,178			-			32,551
	Goodwill		-			73,687			1,779			-			75,466
	Notes receivable - affiliates		-			3,903			-			(3,903	)		-
	Debt issuance costs, net		2,149			-			-			-			2,149
	Other assets		-			48			6			1			55
	Total assets	$	4,835		$	234,379		$	13,323		$	(11,947	)	$	240,590
	LIABILITIES, PARENT NET INVESTMENT AND OWNERS' EQUITY
	Current liabilities:
	Accounts payable	$	-		$	1,708		$	965		$	-		$	2,673
	Accounts payable - affiliates		-			-			8,044			(8,044	)		-
Accrued payroll and other		19			10,544			99			-			10,662
Income taxes payable		-			14,988			1,170			-			16,158
Total current liabilities		19			27,240			10,278			(8,044	)		29,493
Long-term debt		-			75,000			-			-			75,000
Notes payable - affiliates		-			-			3,795			(3,795	)		-
Deferred tax liabilities		-			-			541			-			541
Asset retirement obligations		-			9			-			-			9
Total liabilities		19			102,249			14,614			(11,839	)		105,043
Commitments and contingencies - Note 10
Total parent net investment and owners' equity		4,816			132,130			(1,291	)		(108	)		135,547
Total liabilities, parent net investment and owners' equity	$	4,835		$	234,379		$	13,323		$	(11,947	)	$	240,590
Condensed Income Statement [Table Text Block]								Non-			Consolidation
		Parent			Guarantors			Guarantors			Adjustments			Consolidated
	Revenues	$	-		$	370,081		$	34,337		$	-		$	404,418
	Costs of services		-			323,821			31,534			-			355,355
	Gross margin		-			46,260			2,803			-			49,063
	Operating costs and expense:
	General and administrative		-			19,257			2,064			-			21,321
	Depreciation, amortization and accretion		-			6,136			209			-			6,345
	Impairments		-			32,546			-			-			32,546
	Operating income		-			(11,679	)		530			-			(11,149	)
	Other income (expense):
	Equity earnings (loss) in subsidiaries		(14,134	)		-			-			14,134			-
	Interest expense, net		(983	)		(1,892	)		(333	)		-			(3,208	)
	Offering costs		(446	)		-			-			-			(446	)
	Other, net		-			84			8			-			92
	Net income before income tax expense		(15,563	)		(13,487	)		205			14,134			(14,711	)
	Income tax expense		-			356			112			-			468
	Net income		(15,563	)		(13,843	)		93			14,134			(15,179	)
	Net income attributable to non-controlling interests		4,646			291			-			36			4,973
	Net income attributable to controlling interests	$	(20,209	)	$	(14,134	)	$	93		$	14,098		$	(20,152	)
								Non-			Consolidation
		Parent			Guarantors			Guarantors			Adjustments			Consolidated
	Revenues	$	-		$	222,250		$	26,883		$	-		$	249,133
	Costs of services		-			188,928			24,762			-			213,690
	Gross margin		-			33,322			2,121			-			35,443
	Operating costs and expense:
	General and administrative		-			11,283			1,184			-			12,467
	Depreciation, amortization and accretion		-			5,027			137			-			5,164
	Impairments		-			3,429			702			-			4,131
	Operating income		-			13,583			98			-			13,681
	Other income (expense):
	Equity earnings (loss) in subsidiaries		-			-			-			-			-
	Interest expense, net		(18	)		(3,822	)		(160	)		-			(4,000	)
	Offering costs		(1,376	)		-			-			-			(1,376	)
	Gain on reversal of contingent consideration		-			11,250			-			-			11,250
	Other, net		-			41			(4	)		-			37
	Net income (loss) before income tax expense		(1,394	)		21,052			(66	)		-			19,592
	Income tax expense		-			14,187			1,050			-			15,237
	Net income (loss)		(1,394	)		6,865			(1,116	)		-			4,355
	Net income attributable to non-controlling interests		-			22			-			-			22
	Net income (loss) attributable to controlling interests	$	(1,394	)	$	6,843		$	(1,116	)	$	-		$	4,333
Condensed Statement of Comprehensive Income [Table Text Block]								Non-			Consolidation
		Parent			Guarantors			Guarantors			Adjustments			Consolidated
	Net income (loss)	$	(15,563	)	$	(13,843	)	$	93		$	14,134		$	(15,179	)
	Other comprehensive (loss):
	Foreign currency translation		-			-			(621	)		(316	)		(937	)
	Comprehensive income (loss)	$	(15,563	)	$	(13,843	)	$	(528	)	$	13,818		$	(16,116	)
	Comprehensive income (loss) attributable to non-controlling interests		4,646			291			-			(279	)		4,658
	Comprehensive income (loss) attributable to controlling interests	$	(20,209	)	$	(14,134	)	$	(528	)	$	14,097		$	(20,774	)
								Non-			Consolidation
		Parent			Guarantors			Guarantors			Adjustments			Consolidated
	Net income (loss)	$	(1,394	)	$	6,865		$	(1,116	)	$	-		$	4,355
	Other comprehensive (loss):
	Foreign currency translation		-			-			(112	)		-			(112	)
	Comprehensive income (loss)	$	(1,394	)	$	6,865		$	(1,228	)	$	-		$	4,243
	Comprehensive income attributable to non-controlling interests		-			22			-			-			22
	Comprehensive income (loss) attributable to controlling interests	$	(1,394	)	$	6,843		$	(1,228	)	$	-		$	4,221
Condensed Cash Flow Statement [Table Text Block]								Non-			Consolidation
		Parent			Guarantors			Guarantors			Adjustments			Consolidated
	Operating activities:
	Net income (loss)	$	(15,563	)	$	(13,843	)	$	93		$	14,134		$	(15,179	)
	Adjustments to reconcile net income (loss) to cash provided by (used in) operating activities:
	Depreciation, amortization and accretion		-			6,337			176			-			6,513
	Impairments		-			32,546			-			-			32,546
	Loss on asset disposal		-			3			-			-			3
	Interest expense from debt issuance cost amortization		714			-			-			-			714
	Amortization of equity-based compensation		785			-			-			-			785
	Equity earnings in investee company		-			(46	)		-			-			(46	)
	Distributions from investee company		-			55			-			-			55
	Equity earnings in subsidiaries		14,134			-			-			(14,134	)		-
	Deferred tax benefit, net		-			(15	)		2			-			(13	)
	Non-cash allocated GP expenses		-			497			-			-			497
	Changes in assets and liabilities:
	Trade accounts receivable		(22	)		4,145			2,527			-			6,650
	Prepaid expenses and other		744			(1,600	)		(77	)		-			(933	)
	Accounts payable and accrued payroll and other		21			(3,121	)		136			-			(2,964	)
	Income taxes payable		-			(14,481	)		(1,131	)		-			(15,612	)
	Net cash provided by operating activities		813			10,477			1,726			-			13,016
	Investing activities:
	Acquisition of business		-			(1,769	)		-			-			(1,769	)
	Purchase of property and equipment		-			(517	)		-			-			(517	)
	Net cash used in investing activities		-			(2,286	)		-			-			(2,286	)
	Financing activities:
	Proceeds from initial public offering		80,213			-			-			-			80,213
	Distribution of initial public offering proceeds to Cypress Energy Holdings, LLC		(80,213	)		-			-			-			(80,213	)
	Payment of deferred offering costs		(314	)		-			-			-			(314	)
	Advances on long-term debt		-			7,600			-			-			7,600
	Repayment of long-term debt		-			(5,000	)		-			-			(5,000	)
	Debt issuance costs		(883	)		-			-			-			(883	)
	Contributions from general partner		-			(168	)		-			-			(168	)
	Net advances from members		(105	)		587			-			-			482
	Distributions from subsidiaries		14,535			(14,535	)		-			-			-
	Distributions to limited partners		(13,064	)		-			-			-			(13,064	)
	Distributions to non-controlling members of the TIR Entities		-			(4,683	)		-			-			(4,683	)
	Net cash provided by (used in) financing activities		169			(16,199	)		-			-			(16,030	)
	Effects of exchange rates on cash		-			-			(633	)		-			(633	)
	Net increase (decrease) in cash and cash equivalents		982			(8,008	)		1,093			-			(5,933	)
	Cash and cash equivalents, beginning of period		-			24,606			2,084			-			26,690
	Cash and cash equivalents, end of period	$	982		$	16,598		$	3,177		$	-		$	20,757
	Non-cash items:
	Accounts payable excluded from capital expenditures	$	-		$	756		$	-		$	-		$	756
	Supplemental cash flow disclosures:
	Cash taxes paid		-			16,420			254			-		$	16,674
	Cash interest paid		-			2,415			-			-			2,415
								Non-			Consolidation
		Parent			Guarantors			Guarantors			Adjustments			Consolidated
	Operating activities:
	Net income (loss)	$	(1,394	)	$	6,865		$	(1,116	)	$	-		$	4,355
	Adjustments to reconcile net income (loss) to net cash provided by (used in) operating activities:
	Depreciation, amortization and accretion		-			5,124			137			-			5,261
	Impairments		-			3,429			702			-			4,131
	Gain on reversal of contingent consideration		-			(11,250	)		-			-			(11,250	)
	Interest expense from debt issuance cost amortization		-			1,219			-			-			1,219
	Equity earnings in investee company		-			(32	)		-			-			(32	)
	Deferred tax benefit, net		-			(1,751	)		(265	)		-			(2,016	)
	Stock option expense		-			90			-			-			90
	Changes in assets and liabilities:
	Trade accounts receivable		-			(10,705	)		1,912			-			(8,793	)
	Prepaid expenses and other		(147	)		395			35			-			283
	Accounts payable and accrued payroll and other		19			(2,843	)		914			-			(1,910	)
	Income taxes payable		-			14,417			1,399			-			15,816
Net cash provided by (used in) operating activities		(1,522	)		4,958			3,718			-			7,154
Investing activities:
Cash acquired - TIR Entities		-			6,628			3,480			-			10,108
Acquisition of business		-			(500	)		-			-			(500	)
Purchase of property and equipment		-			(3,829	)		-			-			(3,829	)
Net cash provided by investing activities		-			2,299			3,480			-			5,779
Payment of deferred offering costs		(2,539	)		-			-			-			(2,539	)
Advances on long-term debt		-			75,000			-			-			75,000
Repayment of long-term debt		-			(14,361	)		(5,024	)		-			(19,385	)
Net payments on factoring agreement		-			(36,748	)		-			-			(36,748	)
Payment of debt issuance costs		(2,149	)		(1,219	)		-			-			(3,368	)
Payments on behalf of affiliates		-			(5,763	)		-			-			(5,763	)
Purchase of non-controlling interests		-			(572	)		-			-			(572	)
Tax benefit of stock options exercised		-			528			-			-			528
Contributions from general partner		6,210			-			-			-			6,210
Net cash provided by (used in) financing activities		1,522			16,865			(5,024	)		-			13,363
Effect of exchange rates on cash		-			-			(90	)		-			(90	)
Net increase in cash and cash equivalents		-			24,122			2,084			-			26,206
Cash and cash equivalents, beginning of period		-			484			-			-			484
Cash and cash equivalents, end of period	$	-		$	24,606		$	2,084		$	-		$	26,690
Non-cash items:
Accounts payable excluded from capital expenditures	$	-		$	330		$	-		$	-		$	330
Supplemental cash flow disclosures:
Cash taxes paid	$	-		$	717		$	100		$	-		$	817
Cash interest paid		-			3,917			-			-			3,917

Quarterly_Financial_Informatio1

Quarterly Financial Information (unaudited) (Tables)	12 Months Ended
	Dec. 31, 2014
Quarterly Financial Information Disclosure [Abstract]
Schedule of Quarterly Financial Information [Table Text Block]	2014	Quarter Ended,
		( in thousands, except per unit amounts )
		March 31,		June 30,		September 30,		December 31,
	Revenues	$	97,523	$	93,722	$	111,016	$	102,157
	Gross margin		11,420		12,303		13,281		12,059
	Impairments		-		-		-		32,546
	Net income (loss)		3,517		4,929		5,097		(28,722	)
	Net income (loss) attributable to partners		2,744		3,680		3,555		(30,131	)
	Net income (loss) per common limited partner unit – basic		0.18		0.31		0.3		(2.51	)
	Net income (loss) per common limited partner unit – diluted		0.17		0.31		0.3		(2.51	)
	Net income (loss) per subordinated limited partner unit –basic and diluted		0.18		0.31		0.3		(2.51	)
	2013	Quarter Ended,
		( in thousands )
		March 31,		June 30,		September 30,		December 31,
	Revenues	$	5,337	$	9,176	$	116,980	$	117,640
	Gross margin		3,755		3,725		14,311		13,652
	Impairments		-		-		-		4,131
	Gain on reversal of contingent consideration		-		11,250		-		-
	Income tax expense		-		53		1,211		13,973
	Net income		2,231		12,824		4,488		(15,188	)
	Net income attributable to controlling interests		2,231		12,824		4,488		(15,210	)

Note_1_Organization_and_Operat1

Note 1 - Organization and Operations (Details)	12 Months Ended	0 Months Ended
	Dec. 31, 2014	Mar. 15, 2012
Note 1 - Organization and Operations (Details) [Line Items]
Number Of Other Non Operating Subsidiaries Entity Has Interest	3
Member Interest as Percentage in Managed Wells	25.00%
Pipeline Inspection and Integrity Services [Member] | CANADA
Note 1 - Organization and Operations (Details) [Line Items]
Number of Wholly Owned Subsidiaries	2
Common Units [Member] | Tir Entities [Member] | Cypress Energy Holdings Llc and Affiliates [Member]
Note 1 - Organization and Operations (Details) [Line Items]
Business Acquisition, Equity Interest Issued or Issuable, Number of Shares (in Shares)	929,250
Common Units [Member] | Cypress Energy Holdings II Llc [Member]
Note 1 - Organization and Operations (Details) [Line Items]
Business Acquisition, Equity Interest Issued or Issuable, Number of Shares (in Shares)	671,250
Subordinated Units [Member] | Tir Entities [Member] | Cypress Energy Holdings Llc and Affiliates [Member]
Note 1 - Organization and Operations (Details) [Line Items]
Business Acquisition, Equity Interest Issued or Issuable, Number of Shares (in Shares)	929,250
Subordinated Units [Member] | Cypress Energy Holdings II Llc [Member]
Note 1 - Organization and Operations (Details) [Line Items]
Business Acquisition, Equity Interest Issued or Issuable, Number of Shares (in Shares)	4,983,750
North Dakota [Member]
Note 1 - Organization and Operations (Details) [Line Items]
Number Of Commercial Saltwater Disposal Facilities	8
Texas [Member]
Note 1 - Organization and Operations (Details) [Line Items]
Number Of Commercial Saltwater Disposal Facilities	2
Tir Entities [Member] | Cypress Energy Holdings Llc and Affiliates [Member]
Note 1 - Organization and Operations (Details) [Line Items]
Subsidiary of Limited Liability Company or Limited Partnership, Ownership Interest	50.10%
Limited Liability Company (LLC) or Limited Partnership (LP), Members or Limited Partners, Ownership Interest	15.70%
Ownership Interests Not Contributed To Partnership	49.90%
SBG Energy Services, LLC [Member] | Cypress Energy Partners Llc [Member]
Note 1 - Organization and Operations (Details) [Line Items]
Business Acquisition, Percentage of Voting Interests Acquired by Third Party		100.00%
Number of Businesses Acquired		7
Cypress Energy Holdings II Llc [Member]
Note 1 - Organization and Operations (Details) [Line Items]
Subsidiary of Limited Liability Company or Limited Partnership, Ownership Interest	100.00%
Limited Liability Company (LLC) or Limited Partnership (LP), Members or Limited Partners, Ownership Interest	47.80%
Cypress Energy Services Llc [Member]
Note 1 - Organization and Operations (Details) [Line Items]
Subsidiary of Limited Liability Company or Limited Partnership, Ownership Interest	51.00%
Additional Saltwater Disposal Facilities	3

Note_2_Basis_of_Presentation_a1

Note 2 - Basis of Presentation and Significant Accounting Policies (Details) (USD $)	3 Months Ended				12 Months Ended
	Dec. 31, 2013		Sep. 30, 2013	Jun. 30, 2013	Dec. 31, 2014	Dec. 31, 2013		Dec. 31, 2012
Note 2 - Basis of Presentation and Significant Accounting Policies (Details) [Line Items]
Number of Subsidiaries								4
Partners' Capital Account, Contributions					$500,000	$6,200,000
Income Tax Expense (Benefit)	13,973,000		1,211,000	53,000	468,000	15,237,000	[1]	0
Minimum Percentage of Gross Income Required from Certain Qualifying Sources					90.00%
Allowance for Doubtful Accounts Receivable	200,000				200,000	200,000
Provision for Doubtful Accounts					100,000	400,000		0
Number of Major Customers					3
Impairment of Long-Lived Assets to be Disposed of					12,800,000	3,400,000
Goodwill	75,466,000	[1]			55,545,000	75,466,000	[1]	33,877,000
Goodwill, Impairment Loss					19,773,000
W&ES [Member] | Minimum [Member]
Note 2 - Basis of Presentation and Significant Accounting Policies (Details) [Line Items]
Oil and Gas Sales Revenue, Percentage					20.00%
Phantom Restricted Units [Member]
Note 2 - Basis of Presentation and Significant Accounting Policies (Details) [Line Items]
Antidilutive Securities Excluded from Computation of Earnings Per Share, Amount (in Shares)					14,520
Maximum [Member]
Note 2 - Basis of Presentation and Significant Accounting Policies (Details) [Line Items]
Cash, FDIC Insured Amount					250,000
Cash CDIC Insured Amount					100,000
Finite-Lived Intangible Asset, Useful Life					20 years
Minimum [Member]
Note 2 - Basis of Presentation and Significant Accounting Policies (Details) [Line Items]
Finite-Lived Intangible Asset, Useful Life					5 years
Accounts Receivable [Member]
Note 2 - Basis of Presentation and Significant Accounting Policies (Details) [Line Items]
Number of Major Customers					2
Trade Names [Member]
Note 2 - Basis of Presentation and Significant Accounting Policies (Details) [Line Items]
Impairment of Intangible Assets, Finite-lived					$700,000
SBG Energy Services Llc [Member]
Note 2 - Basis of Presentation and Significant Accounting Policies (Details) [Line Items]
Noncontrolling Interest, Ownership Percentage by Noncontrolling Owners	49.00%				49.00%	49.00%
Cypress Energy Holdings Llc and Affiliates [Member]
Note 2 - Basis of Presentation and Significant Accounting Policies (Details) [Line Items]
Noncontrolling Interest, Ownership Percentage by Noncontrolling Owners					49.90%
[1]	Recast - Note 2

Note_3_Initial_Public_Offering1

Note 3 - Initial Public Offering (Details) (USD $)	10 Months Ended		12 Months Ended
	Dec. 31, 2012		Dec. 31, 2014	Dec. 31, 2013
Initial Public Offering [Abstract]
Partners' Capital Account, Units, Sold in Public Offering (in Shares)			4,312,500
Share Price (in Dollars per share)			$20
Partners Capital Account Distribution Per Unit of Limited Partner Interest Net (in Shares)			18.7
Number of Units Exercised by Underwriters (in Shares)			562,500
Partners' Capital Account, Public Sale of Units Net of Offering Costs			$80,200,000
Total Deferred Offering Costs Charged Against Proceeds from Ipo			2,900,000
Payments of Stock Issuance Costs	0	[1]	314,000	2,539,000	[1]
Offering Costs			$446,000	$1,376,000	[1]
[1]	Recast - Note 2

Note_4_Business_Combinations_D

Note 4 - Business Combinations (Details) (USD $)	0 Months Ended	9 Months Ended	12 Months Ended		1 Months Ended
	Dec. 01, 2014	Sep. 30, 2013	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Salt Water Disposal Facility [Member]
Note 4 - Business Combinations (Details) [Line Items]
Business Combination, Consideration Transferred	$1,700,000
Business Combination, Acquisition Related Costs			400,000
Business Acquisition, Percentage of Voting Interests Acquired		25.00%
Payments to Acquire Businesses, Gross		500,000
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Intangible Assets, Other than Goodwill	241,000
CES [Member]
Note 4 - Business Combinations (Details) [Line Items]
Business Combination, Consideration Transferred				1,400,000
Business Acquisition, Percentage of Voting Interests Acquired by Third Party				49.00%
Business Combination, Consideration Transferred, Purchase Option				700,000
SBG Energy Services, LLC [Member] | Customer Relationships [Member]
Note 4 - Business Combinations (Details) [Line Items]
Finite-Lived Intangible Assets, Remaining Amortization Period				5 years
SBG Energy Services, LLC [Member]
Note 4 - Business Combinations (Details) [Line Items]
Business Combination, Consideration Transferred				700,000	47,300,000
Business Acquisition, Percentage of Voting Interests Acquired					100.00%
Business Combination, Consideration Transferred, Purchase Option				200,000
Number of Water Disposal Wells Acquired					6
Option to Purchase Interest in Assets Specified as Percentage					51.00%
Purchase Price to Purchase Interest in Certain Assets and Ownership Interest					500,000
Percentage of Ownership Interests to Be Acquired Under Purchase Option					25.00%
Adjustment Amount of Well Improvement and Construction Reserves					8,200,000
Percentage of Profitability Thresholds for Contingent Consideration Due					50.00%
Amount of EBITDA to Be Attained					12,800,000
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Intangible Assets, Other than Goodwill		150,000
Moxie [Member] | Noncompete Agreements [Member]
Note 4 - Business Combinations (Details) [Line Items]
Finite-Lived Intangible Assets, Remaining Amortization Period				3 years
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Intangible Assets, Other than Goodwill				100,000
Moxie [Member]
Note 4 - Business Combinations (Details) [Line Items]
Business Combination, Consideration Transferred					23,900,000
Number of Water Disposal Wells Acquired					4
Number of Agreements to Acquire Wells					2
Term of Noncompete Agreements				36 months
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Intangible Assets, Other than Goodwill					60,000
SBG [Member]
Note 4 - Business Combinations (Details) [Line Items]
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Contingent Liability					11,250,000
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Intangible Assets, Other than Goodwill					225,000
Moxie and SBG Acquisition [Member]
Note 4 - Business Combinations (Details) [Line Items]
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Contingent Liability					11,250,000
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Intangible Assets, Other than Goodwill					$285,000

Note_4_Business_Combinations_D1

Note 4 - Business Combinations (Details) - Fair Value of Assets Acquired and Liabilities Assumed (Salt Water Disposal Facility [Member], USD $)	Dec. 01, 2014
In Thousands, unless otherwise specified
Salt Water Disposal Facility [Member]
Note 4 - Business Combinations (Details) - Fair Value of Assets Acquired and Liabilities Assumed [Line Items]
Current assets	$50
Property and equipment	1,837
Intangible assets - contracts	241
Total value of assets acquired	2,128
Current liabilities assumed	386
Asset retirement obligation	1
Net assets acquired	$1,741

Note_4_Business_Combinations_D2

Note 4 - Business Combinations (Details) - Fair Value of Assets Acquired and Liabilities Assumed (USD $)	Dec. 31, 2014	Dec. 31, 2013		Dec. 31, 2012	Jun. 26, 2013
In Thousands, unless otherwise specified
Intangible assets:
Goodwill	$55,545	$75,466	[1]	$33,877
Tulsa Inspection Resources Entities [Member] | Trademarks and Trade Names [Member]
Intangible assets:
Intangible assets					10,850
Tulsa Inspection Resources Entities [Member] | Database Rights [Member]
Intangible assets:
Intangible assets					2,080
Tulsa Inspection Resources Entities [Member] | Customer Relationships [Member]
Intangible assets:
Intangible assets					21,380
Tulsa Inspection Resources Entities [Member]
Note 4 - Business Combinations (Details) - Fair Value of Assets Acquired and Liabilities Assumed [Line Items]
Cash					10,108
Other working capital, net					33,990
Property and equipment					1,075
Intangible assets:
Goodwill					40,638
Total value of assets acquired					120,121
Mezzanine debt					19,756
Factoring debt					36,748
Total liabilities assumed					56,504
Net assets acquired					$63,617
[1]	Recast - Note 2

Note_4_Business_Combinations_D3

Note 4 - Business Combinations (Details) - Fair Value of Assets Acquired and Liabilities Assumed (USD $)	Dec. 31, 2014	Dec. 31, 2013		Dec. 31, 2012	Sep. 30, 2013
In Thousands, unless otherwise specified
Note 4 - Business Combinations (Details) - Fair Value of Assets Acquired and Liabilities Assumed [Line Items]
Goodwill	$55,545	$75,466	[1]	$33,877
SBG Energy Services, LLC [Member]
Note 4 - Business Combinations (Details) - Fair Value of Assets Acquired and Liabilities Assumed [Line Items]
Current assets					35
Property and equipment					300
Intangible assets - customer relationships					150
Goodwill					971
Total assets acquired					1,456
Current liabilities					35
Net assets acquired					$1,421
[1]	Recast - Note 2

Note_4_Business_Combinations_D4

Note 4 - Business Combinations (Details) - Fair Value of Assets Acquired and Liabilities Assumed (USD $)	Dec. 31, 2014	Dec. 31, 2013		Dec. 31, 2012
In Thousands, unless otherwise specified
Fair value of net assets:
Goodwill	$55,545	$75,466	[1]	$33,877
Moxie [Member]
Fair value of net assets:
Current assets				288
Property and equipment				16,634
Intangible assets				60
Goodwill				6,903
Total assets acquired				23,885
Asset retirement obligations				3
Total liabilities assumed				3
Total purchase price				23,882
SBG [Member]
Fair value of net assets:
Current assets				2,947
Property and equipment				30,017
Related-party notes receivable				438
Intangible assets				225
Goodwill				26,974
Total assets acquired				60,601
Current liabilities				500
Related-party notes payable				1,534
Contingent consideration due sellers				11,250
Asset retirement obligations				5
Total liabilities assumed				13,289
Total purchase price				47,312
Moxie and SBG Acquisition [Member]
Fair value of net assets:
Current assets				3,235
Property and equipment				46,651
Related-party notes receivable				438
Intangible assets				285
Goodwill				33,877
Total assets acquired				84,486
Current liabilities				500
Related-party notes payable				1,534
Contingent consideration due sellers				11,250
Asset retirement obligations				8
Total liabilities assumed				13,292
Total purchase price				$71,194
[1]	Recast - Note 2

Note_4_Business_Combinations_D5

Note 4 - Business Combinations (Details) - Pro Forma Results of Operations (USD $)	3 Months Ended								10 Months Ended		12 Months Ended
In Thousands, unless otherwise specified	Dec. 31, 2014	Sep. 30, 2014	Jun. 30, 2014	Mar. 31, 2014	Dec. 31, 2013	Sep. 30, 2013	Jun. 30, 2013	Mar. 31, 2013	Dec. 31, 2012		Dec. 31, 2014	Dec. 31, 2013		Dec. 31, 2012
Note 4 - Business Combinations (Details) - Pro Forma Results of Operations [Line Items]
Revenue as reported	$102,157	$111,016	$93,722	$97,523	$117,640	$116,980	$9,176	$5,337	$619		$404,418	$249,133	[1]	$619
Business Combinations:
Pro-forma revenue											404,715	402,936		246,190
Net income (loss) as reported	-28,722	5,097	4,929	3,517	-15,188	4,488	12,824	2,231	-1,845	[1]	-15,179	4,355	[1]	-1,845
Business Combinations:
Pro-forma net income (loss)											-15,392	5,435		6,670
SWD Facility [Member]
Business Combinations:
Pro-forma revenue											297
Business Combinations:
Pro-forma net income (loss)											-213
Tulsa Inspection Resources Entities [Member]
Business Combinations:
Pro-forma revenue												152,989		233,803
Business Combinations:
Pro-forma net income (loss)												953		2,662
SBG Energy Services, LLC [Member]
Business Combinations:
Pro-forma revenue												814
Business Combinations:
Pro-forma net income (loss)												127
SBG [Member]
Business Combinations:
Pro-forma revenue														8,588
Business Combinations:
Pro-forma net income (loss)														4,462
Moxie [Member]
Business Combinations:
Pro-forma revenue														3,180
Business Combinations:
Pro-forma net income (loss)														$1,391
[1]	Recast - Note 2

Note_5_Property_and_Equipment_1

Note 5 - Property and Equipment (Details) (USD $)	3 Months Ended		12 Months Ended
	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Note 5 - Property and Equipment (Details) [Line Items]
Depreciation			$4,100,000	$4,100,000	$100,000
Cost of Services, Depreciation			200,000	100,000
Accumulated Depreciation, Depletion and Amortization, Property, Plant and Equipment, Period Increase (Decrease)			-4,300,000	-600,000
Impairment of Long-Lived Assets Held-for-use	32,546,000	4,131,000
Predecessor [Member]
Note 5 - Property and Equipment (Details) [Line Items]
Depreciation					1,200,000
SWD Facility [Member]
Note 5 - Property and Equipment (Details) [Line Items]
Number of Facilities Impaired			5	1
Impaired Assets to be Disposed of by Method Other than Sale, Carrying Value of Asset	20,000,000	4,500,000	20,000,000	4,500,000
Property, Plant, and Equipment, Fair Value Disclosure	7,200,000	1,100,000	7,200,000	1,100,000
Impairment of Long-Lived Assets Held-for-use			$12,773,000	$3,427,000

Note_5_Property_and_Equipment_2

Note 5 - Property and Equipment (Details) - Property and Equipment (USD $)	12 Months Ended
In Thousands, unless otherwise specified	Dec. 31, 2014	Dec. 31, 2013
Property, Plant and Equipment [Line Items]
Property, plant and equipment, gross	$27,878	$42,529	[1]
Less accumulated depreciation	-3,538	-3,711	[1]
Net property and equipment	24,340	38,818	[1]
Land [Member]
Property, Plant and Equipment [Line Items]
Property, plant and equipment, gross	2,049	2,049
Land Improvements [Member]
Property, Plant and Equipment [Line Items]
Property, plant and equipment, useful lives	15 years
Property, plant and equipment, gross	1,143	2,543
Building and Building Improvements [Member]
Property, Plant and Equipment [Line Items]
Property, plant and equipment, useful lives	39 years
Property, plant and equipment, gross	1,056	1,767
Wells and Related Equipment and Facilities [Member] | Minimum [Member]
Property, Plant and Equipment [Line Items]
Property, plant and equipment, useful lives	5 years
Wells and Related Equipment and Facilities [Member] | Maximum [Member]
Property, Plant and Equipment [Line Items]
Property, plant and equipment, useful lives	15 years
Wells and Related Equipment and Facilities [Member]
Property, Plant and Equipment [Line Items]
Property, plant and equipment, gross	22,666	35,326
Office Equipment [Member] | Minimum [Member]
Property, Plant and Equipment [Line Items]
Property, plant and equipment, useful lives	3 years
Office Equipment [Member] | Maximum [Member]
Property, Plant and Equipment [Line Items]
Property, plant and equipment, useful lives	9 years
Office Equipment [Member]
Property, Plant and Equipment [Line Items]
Property, plant and equipment, gross	816	771
Property, Plant and Equipment, Other Types [Member] | Minimum [Member]
Property, Plant and Equipment [Line Items]
Property, plant and equipment, useful lives	3 years
Property, Plant and Equipment, Other Types [Member] | Maximum [Member]
Property, Plant and Equipment [Line Items]
Property, plant and equipment, useful lives	5 years
Property, Plant and Equipment, Other Types [Member]
Property, Plant and Equipment [Line Items]
Property, plant and equipment, gross	$148	$73
[1]	Recast - Note 2

Note_5_Property_and_Equipment_3

Note 5 - Property and Equipment (Details) - Impaired Property and Equipment by Category (USD $)	3 Months Ended			12 Months Ended
In Thousands, unless otherwise specified	Dec. 31, 2014	Dec. 31, 2013		Dec. 31, 2014	Dec. 31, 2013
Asset Category
Property and equipment, gross	$27,878	$42,529	[1]	$27,878	$42,529	[1]
Accumulated depreciation	-3,538	-3,711	[1]	-3,538	-3,711	[1]
Impairment of facilities	32,546	4,131
SWD Facility [Member] | Land Improvements [Member]
Asset Category
Property and equipment, gross	1,514	725		1,514	725
SWD Facility [Member] | Building and Building Improvements [Member]
Asset Category
Property and equipment, gross	748	135		748	135
SWD Facility [Member] | Wells and Related Equipment and Facilities [Member]
Asset Category
Property and equipment, gross	14,796	2,964		14,796	2,964
SWD Facility [Member]
Asset Category
Property and equipment, gross	17,058	3,824		17,058	3,824
Accumulated depreciation	-4,285	-397		-4,285	-397
Impairment of facilities				12,773	3,427
Land Improvements [Member]
Asset Category
Property and equipment, gross	1,143	2,543		1,143	2,543
Building and Building Improvements [Member]
Asset Category
Property and equipment, gross	1,056	1,767		1,056	1,767
Wells and Related Equipment and Facilities [Member]
Asset Category
Property and equipment, gross	$22,666	$35,326		$22,666	$35,326
[1]	Recast - Note 2

Note_6_Goodwill_Details

Note 6 - Goodwill (Details) (USD $)	12 Months Ended
In Thousands, unless otherwise specified	Dec. 31, 2014
Note 6 - Goodwill (Details) [Line Items]
Goodwill, Impairment Loss	$19,773
Water and Environmental Services [Member] | Minimum [Member]
Note 6 - Goodwill (Details) [Line Items]
Oil and Gas Sales Revenue, Percentage	20.00%
Water and Environmental Services [Member]
Note 6 - Goodwill (Details) [Line Items]
Goodwill, Impairment Loss	$19,773

Note_6_Goodwill_Details_Summar

Note 6 - Goodwill (Details) - Summary of Changes in Goodwill (USD $)	12 Months Ended
In Thousands, unless otherwise specified	Dec. 31, 2014		Dec. 31, 2013
Goodwill [Line Items]
Balance	$75,466	[1]	$33,877
Impairments	-19,773
Goodwill from business combinations			41,609
Foreign currency translation	-148		-20
Balance	55,545		75,466	[1]
Water and Environmental Services [Member]
Goodwill [Line Items]
Balance	34,848		33,877
Impairments	-19,773
Goodwill from business combinations			971
Foreign currency translation	0		0
Balance	15,075		34,848
Pipeline Inspection and Integrity Services [Member]
Goodwill [Line Items]
Balance	40,618		0
Impairments	0
Goodwill from business combinations			40,638
Foreign currency translation	-148		-20
Balance	$40,470		$40,618
[1]	Recast - Note 2

Note_7_Intangible_Assets_Detai

Note 7 - Intangible Assets (Details) (USD $)	12 Months Ended
	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Note 7 - Intangible Assets (Details) [Line Items]
Amortization of Intangible Assets	$2,400,000	$1,300,000	$0
Pipeline Inspection and Integrity Services [Member] | Trade Names [Member]
Note 7 - Intangible Assets (Details) [Line Items]
Impairment of Intangible Assets (Excluding Goodwill)		$700,000

Note_7_Intangible_Assets_Detai1

Note 7 - Intangible Assets (Details) - Finite-lived Intangible Assets (USD $)	12 Months Ended
In Thousands, unless otherwise specified	Dec. 31, 2014	Dec. 31, 2013
Finite-Lived Intangible Assets [Line Items]
Gross carrying amount	$34,026	$33,785
Accumulated amortization	3,781	1,234
Minimum [Member] | Customer Relationships [Member]
Finite-Lived Intangible Assets [Line Items]
Useful lives	5 years
Minimum [Member]
Finite-Lived Intangible Assets [Line Items]
Useful lives	5 years
Maximum [Member] | Customer Relationships [Member]
Finite-Lived Intangible Assets [Line Items]
Useful lives	20 years
Maximum [Member]
Finite-Lived Intangible Assets [Line Items]
Useful lives	20 years
Customer Relationships [Member]
Finite-Lived Intangible Assets [Line Items]
Gross carrying amount	21,510	21,510
Accumulated amortization	1,788	554
Contracts [Member]
Finite-Lived Intangible Assets [Line Items]
Useful lives	3 years
Gross carrying amount	241	0
Accumulated amortization	0	0
Noncompete Agreements [Member]
Finite-Lived Intangible Assets [Line Items]
Useful lives	3 years
Gross carrying amount	60	60
Accumulated amortization	41	21
Trademarks and Trade Names [Member]
Finite-Lived Intangible Assets [Line Items]
Useful lives	10 years
Gross carrying amount	10,135	10,135
Accumulated amortization	1,638	553
Database Rights [Member]
Finite-Lived Intangible Assets [Line Items]
Useful lives	10 years
Gross carrying amount	2,080	2,080
Accumulated amortization	$314	$106

Note_7_Intangible_Assets_Detai2

Note 7 - Intangible Assets (Details) - Future Amortization Expense of Intangible Assets (USD $)	Dec. 31, 2014
In Thousands, unless otherwise specified
Future Amortization Expense of Intangible Assets [Abstract]
2015	$2,468
2016	2,391
2017	2,391
2018	2,305
2019	2,281
Thereafter	18,409
	$30,245

Note_8_Credit_Agreement_Detail

Note 8 - Credit Agreement (Details) (USD $)	12 Months Ended
	Dec. 31, 2014	Oct. 21, 2014	Dec. 31, 2013		Dec. 24, 2013
Note 8 - Credit Agreement (Details) [Line Items]
Line of Credit Facility, Maximum Borrowing Capacity		$200,000,000			$120,000,000
Line of Credit Facility Additional Borrowings		125,000,000
Long-term Line of Credit	77,600,000		75,000,000	[1]
Line of Credit Facility, Commitment Fee Percentage	0.50%
Debt Covenant Total Adjusted Leverage Ratio Maximum	4
Debt Covenant Interest Coverage Ratio Minimum	3
Total Adjusted Leverage Ratio	0.94
Interest Coverage Ratio	9.14
Percentage of Cash on Hand of Borrowing Base	100.00%
Line of Credit Facility Minimum Extended Available Borrowing Capacity	5,000,000
Amount Borrowing Base Must Exceed Outstanding Balance of Working Capital Revolving Credit Facility	5,000,000
Calculated Borrowing Base Amount	65,300,000
Minimum [Member] | Base Rate [Member]
Note 8 - Credit Agreement (Details) [Line Items]
Debt Instrument, Basis Spread on Variable Rate	1.25%
Minimum [Member] | London Interbank Offered Rate (LIBOR) [Member]
Note 8 - Credit Agreement (Details) [Line Items]
Debt Instrument, Basis Spread on Variable Rate	2.25%
Maximum [Member] | Base Rate [Member]
Note 8 - Credit Agreement (Details) [Line Items]
Debt Instrument, Basis Spread on Variable Rate	2.75%
Maximum [Member] | London Interbank Offered Rate (LIBOR) [Member]
Note 8 - Credit Agreement (Details) [Line Items]
Debt Instrument, Basis Spread on Variable Rate	3.75%
London Interbank Offered Rate (LIBOR) [Member]
Note 8 - Credit Agreement (Details) [Line Items]
Debt Instrument, Interest Rate, Effective Percentage	3.03%		3.14%
Debt, Weighted Average Interest Rate	0.26%		0.23%
Debt Instrument Weighted Average Margin Rate	2.77%		2.92%
Senior Secured Working Capital Revolving Credit Facility [Member]
Note 8 - Credit Agreement (Details) [Line Items]
Line of Credit Facility, Maximum Borrowing Capacity	15,300,000				65,000,000
Line of Credit Facility, Capacity Available for Trade Purchases	25,000,000	75,000,000
Senior Secured Acquisition Revolving Credit Facility [Member]
Note 8 - Credit Agreement (Details) [Line Items]
Line of Credit Facility, Maximum Borrowing Capacity					55,000,000
Line of Credit Facility, Capacity Available for Specific Purpose Other than for Trade Purchases	89,700,000	125,000,000
Line of Credit Facility, Capacity Available for Trade Purchases	$97,400,000
[1]	Recast - Note 2

Note_8_Credit_Agreement_Detail1

Note 8 - Credit Agreement (Details) - Changes in Long-term Debt (USD $)	12 Months Ended
In Thousands, unless otherwise specified	Dec. 31, 2014	Dec. 31, 2013
Debt Instrument [Line Items]
Long term debt	$77,600	$75,000
Net borrowings or repayments	2,600
Senior Secured Acquisition Revolving Credit Facility [Member] | Line of Credit [Member]
Debt Instrument [Line Items]
Long term debt	27,600	25,000
Net borrowings or repayments	2,600
Borrowing Base Revolving Credit Facility [Member] | Line of Credit [Member]
Debt Instrument [Line Items]
Long term debt	$50,000	$50,000

Note_8_Credit_Agreement_Detail2

Note 8 - Credit Agreement (Details) - Changes in Long-term Debt (Parentheticals) (Line of Credit [Member])	Dec. 31, 2014
Senior Secured Acquisition Revolving Credit Facility [Member]
Debt Instrument [Line Items]
Interest rate	3.26%
Borrowing Base Revolving Credit Facility [Member]
Debt Instrument [Line Items]
Interest rate	2.74%

Note_9_Income_Taxes_Details

Note 9 - Income Taxes (Details) (USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2014	Dec. 31, 2013
Note 9 - Income Taxes (Details) [Line Items]
One Time Tax Provision		$15
Effective Income Tax Rate Reconciliation, at Federal Statutory Income Tax Rate, Percent	35.00%
Earliest Tax Year [Member]
Note 9 - Income Taxes (Details) [Line Items]
Open Tax Year	2011
Latest Tax Year [Member]
Note 9 - Income Taxes (Details) [Line Items]
Open Tax Year	2013

Note_9_Income_Taxes_Details_Si

Note 9 - Income Taxes (Details) - Significant Components of Income Tax Expense (Benefit) (USD $)	3 Months Ended			12 Months Ended
In Thousands, unless otherwise specified	Dec. 31, 2013	Sep. 30, 2013	Jun. 30, 2013	Dec. 31, 2014	Dec. 31, 2013		Dec. 31, 2012
Current expense:
Federal				$38	$14,714
State				332	2,462
Canadian				100	285
Total				470	17,461
Deferred tax expense (benefit):
Federal				-12	-1,553
State				-3	-390
Canadian				13	-281
Total				-2	-2,224
Total income tax expense	$13,973	$1,211	$53	$468	$15,237	[1]	$0
[1]	Recast - Note 2

Note_9_Income_Taxes_Details_Co

Note 9 - Income Taxes (Details) - Composition of Deferred Tax Assets and Liabilities (USD $)	Dec. 31, 2014	Dec. 31, 2013
In Thousands, unless otherwise specified
Current deferred tax assets:
Accrued liabilities	$17	$1
Bad debt reserve	0	28
Canadian net operating loss	51	105
Total	68	134	[1]
Non-current deferred tax assets (liabilities):
Property and equipment	2	3
Intangible assets	-440	-544
Total	($438)	($541)
[1]	Recast - Note 2

Note_9_Income_Taxes_Details_In

Note 9 - Income Taxes (Details) - Income Tax Expense on the Consolidated Statements of Operations (USD $)	3 Months Ended			12 Months Ended
In Thousands, unless otherwise specified	Dec. 31, 2013	Sep. 30, 2013	Jun. 30, 2013	Dec. 31, 2014	Dec. 31, 2013		Dec. 31, 2012
Note 9 - Income Taxes (Details) - Income Tax Expense on the Consolidated Statements of Operations [Line Items]
Tax (benefit) computed at statutory rate of 35%				($5,149)	$6,857		($646)
Income not subject to federal taxes				5,274	-4,793		646
State income taxes, net of federal benefit				326	535		0
Tax on conversion of TIR, Inc. to pass through entities				0	12,892		0
Other				17	-254		0
Total income tax expense	13,973	1,211	53	468	15,237	[1]	0
Predecessor [Member]
Note 9 - Income Taxes (Details) - Income Tax Expense on the Consolidated Statements of Operations [Line Items]
Tax (benefit) computed at statutory rate of 35%							2,170
Income not subject to federal taxes							-2,170
State income taxes, net of federal benefit							0
Tax on conversion of TIR, Inc. to pass through entities							0
Other							0
Total income tax expense							$0
[1]	Recast - Note 2

Note_9_Income_Taxes_Details_In1

Note 9 - Income Taxes (Details) - Income Tax Expense on the Consolidated Statements of Operations (Parentheticals)	12 Months Ended
	Dec. 31, 2014
Note 9 - Income Taxes (Details) - Income Tax Expense on the Consolidated Statements of Operations (Parentheticals) [Line Items]
Statutory tax rate	35.00%

Note_10_Parent_Net_Investment_1

Note 10 - Parent Net Investment and Owners' Equity (Details) (USD $)	12 Months Ended
In Millions, except Share data, unless otherwise specified	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Note 10 - Parent Net Investment and Owners' Equity (Details) [Line Items]
Cumalative Advances of Treasury and Accounts Payable Services (in Dollars)	$0.20	$3.50	$0.50
Limited Liability Company (LLC) or Limited Partnership (LP), Managing Member or General Partner, Ownership Interest	0.00%
Incentive Distribution Quarterly Distribution Per Unit (in Dollars per share)	$0.45
Quarter One [Member]
Note 10 - Parent Net Investment and Owners' Equity (Details) [Line Items]
Incentive Distribution Quarterly Distributions of Available Cash from Operating Surplus Percentage	15.00%
Quarter Two [Member]
Note 10 - Parent Net Investment and Owners' Equity (Details) [Line Items]
Incentive Distribution Quarterly Distributions of Available Cash from Operating Surplus Percentage	25.00%
Quarter Three [Member]
Note 10 - Parent Net Investment and Owners' Equity (Details) [Line Items]
Incentive Distribution Quarterly Distributions of Available Cash from Operating Surplus Percentage	50.00%
Common Units [Member]
Note 10 - Parent Net Investment and Owners' Equity (Details) [Line Items]
Limited Partners' Capital Account, Units Outstanding (in Shares)	5,913,000
Distribution Made to Limited Partner, Distributions Declared, Per Unit (in Dollars per share)	$0.39
Subordinated Units [Member]
Note 10 - Parent Net Investment and Owners' Equity (Details) [Line Items]
Limited Partners' Capital Account, Units Outstanding (in Shares)	5,913,000

Note_11_Major_Customers_Detail

Note 11 - Major Customers (Details)	12 Months Ended
	Dec. 31, 2014
Risks and Uncertainties [Abstract]
Number of Major Customers	3

Note_12_Equity_Compensation_De

Note 12 - Equity Compensation (Details) (USD $)	12 Months Ended
In Millions, except Share data, unless otherwise specified	Dec. 31, 2014	Dec. 31, 2013	Jan. 21, 2014	Mar. 31, 2014
Note 12 - Equity Compensation (Details) [Line Items]
Employee Service Share-based Compensation, Nonvested Awards, Compensation Cost Not yet Recognized	$0.50
Employee Service Share-based Compensation, Nonvested Awards, Compensation Cost Not yet Recognized, Period for Recognition	3 years 36 days
Employee Service Share Based Compensation Additional Tax Benefit	0.5
Subordinated Units [Member] | Predecessor Long Term Incentive Plan [Member]
Note 12 - Equity Compensation (Details) [Line Items]
Number of Units Converted (in Shares)	44,451
Subordinated Units [Member]
Note 12 - Equity Compensation (Details) [Line Items]
Allocated Share-based Compensation Expense	0.3
Long Term Incentive Plan [Member] | Minimum [Member]
Note 12 - Equity Compensation (Details) [Line Items]
Share-based Compensation Arrangement by Share-based Payment Award, Award Vesting Period	3 years
Long Term Incentive Plan [Member] | Maximum [Member]
Note 12 - Equity Compensation (Details) [Line Items]
Share-based Compensation Arrangement by Share-based Payment Award, Award Vesting Period	5 years
Long Term Incentive Plan [Member]
Note 12 - Equity Compensation (Details) [Line Items]
Share-based Compensation Arrangement by Share-based Payment Award, Number of Shares Authorized (in Shares)			1,182,600
Percentage of Authorized Units			10.00%
Employee Service Share-based Compensation, Nonvested Awards, Compensation Cost Not yet Recognized	2.1
Employee Service Share-based Compensation, Nonvested Awards, Compensation Cost Not yet Recognized, Period for Recognition	3 years 328 days
Number of Units Exchanged (in Shares)	44,250
Predecessor Long Term Incentive Plan [Member]
Note 12 - Equity Compensation (Details) [Line Items]
Reversal of Compensation Liability				0.1
TIR Inc [Member]
Note 12 - Equity Compensation (Details) [Line Items]
Share-based Compensation Arrangement by Share-based Payment Award, Number of Shares Authorized (in Shares)	14
Allocated Share-based Compensation Expense	1.75
Employee Service Share Based Compensation Tax Provision		0.2
Employee Service Share Based Compensation Additional Tax Benefit	0.6
Employee Service Share-based Compensation, Tax Benefit from Compensation Expense	$0.70

Note_12_Equity_Compensation_De1

Note 12 - Equity Compensation (Details) - Grants and Forfeitures of Units under the LTIP (Long Term Incentive Plan [Member], USD $)	12 Months Ended
In Thousands, except Per Share data, unless otherwise specified	Dec. 31, 2014
Long Term Incentive Plan [Member]
Note 12 - Equity Compensation (Details) - Grants and Forfeitures of Units under the LTIP [Line Items]
Number of Units	158,353
Weighted Average Grant Date Fair Value	$17.36
Units granted	178,264
Units granted	$17.96
Units forfeited	-19,911
Units forfeited	($16.78)

Note_12_Equity_Compensation_De2

Note 12 - Equity Compensation (Details) - Stock Option Activity (USD $)	6 Months Ended
In Thousands, unless otherwise specified	Dec. 31, 2013
Stock Option Activity [Abstract]
Outstanding at	7
Outstanding at	$2,450
Exercised	-5
Exercised	-1,750
Forfeited or expired	-2
Forfeited or expired	($700)

Note_13_RelatedParty_Transacti1

Note 13 - Related-Party Transactions (Details) (USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Omnibus Agreement [Member]
Note 13 - Related-Party Transactions (Details) [Line Items]
Related Party Transaction, Selling, General and Administrative Expenses from Transactions with Related Party	$4
Prorated Annual Administrative Fee	3.8
Costs and Expenses, Related Party	0.5
SBG Disposal, LLC [Member]
Note 13 - Related-Party Transactions (Details) [Line Items]
Costs and Expenses, Related Party		1.8
Rud Transportation, LLC [Member]
Note 13 - Related-Party Transactions (Details) [Line Items]
Revenue from Related Parties	2.1	1.8	0.7
Accounts Receivable, Related Parties, Current	0.3	0.4
Alati Arnegard, LLC [Member]
Note 13 - Related-Party Transactions (Details) [Line Items]
Accounts Receivable, Related Parties, Current	0.1	0.1
Subsidiary of Limited Liability Company or Limited Partnership, Ownership Interest	25.00%
Management Fees Revenue	0.6	0.2
Cypress Energy Management - Bakken Operations, LLC [Member]
Note 13 - Related-Party Transactions (Details) [Line Items]
Increase (Decrease) in Employee Related Liabilities	3.2	0.8
Accounts Payable, Related Parties	0.2	0.1
TIR Inc [Member]
Note 13 - Related-Party Transactions (Details) [Line Items]
Related Party Transaction, Other Revenues from Transactions with Related Party		$0.90
TIR-Foley [Member]
Note 13 - Related-Party Transactions (Details) [Line Items]
Number of Employee Owners		2

Note_14_Commitments_and_Contin2

Note 14 - Commitments and Contingencies (Details) (USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2014	Dec. 31, 2013
Note 14 - Commitments and Contingencies (Details) [Line Items]
Operating Leases, Rent Expense, Net	$0.10	$0.10
Performance Obligation Collateral [Member]
Note 14 - Commitments and Contingencies (Details) [Line Items]
Security Deposit	0.5	0.4
Employment Contract Commitments [Member] | Minimum [Member]
Note 14 - Commitments and Contingencies (Details) [Line Items]
Term Of Employment Agreements	2 years
Employment Contract Commitments [Member] | Maximum [Member]
Note 14 - Commitments and Contingencies (Details) [Line Items]
Term Of Employment Agreements	2 years
Employment Contract Commitments [Member]
Note 14 - Commitments and Contingencies (Details) [Line Items]
Loss Contingency, Estimate of Possible Loss	0.9
Compliance Audit Contingencies [Member]
Note 14 - Commitments and Contingencies (Details) [Line Items]
Loss Contingency, Estimate of Possible Loss	$0.20	$0.40
Minimum [Member] | Salt Water Disposal Facility [Member]
Note 14 - Commitments and Contingencies (Details) [Line Items]
Lessor Leasing Arrangements, Operating Leases, Term of Contract	15 years
Maximum [Member] | Salt Water Disposal Facility [Member]
Note 14 - Commitments and Contingencies (Details) [Line Items]
Lessor Leasing Arrangements, Operating Leases, Term of Contract	20 years
Salt Water Disposal Facility [Member]
Note 14 - Commitments and Contingencies (Details) [Line Items]
Number of Operating Salt Water Disposal Facilities	4

Note_14_Commitments_and_Contin3

Note 14 - Commitments and Contingencies (Details) - Minimum Annual Lease Commitments under the Current Office Lease and Other Operating Leases (USD $)	Dec. 31, 2014
In Thousands, unless otherwise specified
Minimum Annual Lease Commitments under the Current Office Lease and Other Operating Leases [Abstract]
2015	$561
2016	478
2017	389
2018	134
2019	25
Thereafter	557
Total	$2,144

Note_15_Segment_Disclosures_De

Note 15 - Segment Disclosures (Details)	12 Months Ended
	Dec. 31, 2014
Note 15 - Segment Disclosures (Details) [Line Items]
Number of Reportable Segments	2
Water and Environmental Services [Member] | Operating Segments [Member]
Note 15 - Segment Disclosures (Details) [Line Items]
Number of Operating Entities Under Reportable Segment	10

Note_15_Segment_Disclosures_De1

Note 15 - Segment Disclosures (Details) - Reconciliation of Total Segment Operating Income to Net Income before Income Tax Expense (USD $)	3 Months Ended									10 Months Ended		12 Months Ended
In Thousands, unless otherwise specified	Dec. 31, 2014	Sep. 30, 2014	Jun. 30, 2014	Mar. 31, 2014	Dec. 31, 2013		Sep. 30, 2013	Jun. 30, 2013	Mar. 31, 2013	Dec. 31, 2012		Dec. 31, 2014	Dec. 31, 2013		Dec. 31, 2012
Segment Reporting Information [Line Items]
Revenue	$102,157	$111,016	$93,722	$97,523	$117,640		$116,980	$9,176	$5,337	$619		$404,418	$249,133	[1]	$619
Costs of services										309		355,355	213,690	[1]	309
Gross margin	12,059	13,281	12,303	11,420	13,652		14,311	3,725	3,755	310		49,063	35,443	[1]	310
General and administrative expense										2,056		21,321	12,467	[1]	2,056
Impairments										0	[1]	32,546	4,131	[1]
Depreciation, amortization and accretion												6,345	5,164		99
Operating (loss) income										-1,845		-11,149	13,681	[1]	-1,845
Interest expense, net												3,208	4,000	[1]
Offering costs												446	1,376	[1]
Other expense, net												-92	-37	[1]
Net income (loss) before income tax expense										-1,845		-14,711	19,592	[1]
Total Assets	189,842				240,590	[1]						189,842	240,590	[1]
Year ended December 31, 2013
Gain on reversal of contingent consideration								-11,250		0	[1]	0	-11,250	[1]
Predecessor [Member] | Water and Environmental Services [Member]
Segment Reporting Information [Line Items]
Revenue															12,203
Costs of services															3,662
Gross margin															8,541
General and administrative expense															477
Depreciation, amortization and accretion															1,398
Operating (loss) income															6,666
Predecessor [Member] | Pipeline Inspection and Integrity Services [Member]
Segment Reporting Information [Line Items]
Revenue															0
Costs of services															0
Gross margin															0
General and administrative expense															0
Depreciation, amortization and accretion															0
Operating (loss) income															0
Predecessor [Member] | Other Segments [Member]
Segment Reporting Information [Line Items]
Revenue															0
Costs of services															0
Gross margin															0
General and administrative expense															0
Depreciation, amortization and accretion															0
Operating (loss) income															0
Predecessor [Member]
Segment Reporting Information [Line Items]
Revenue															12,203
Costs of services															3,662
Gross margin															8,541
General and administrative expense															477
Impairments															0
Depreciation, amortization and accretion															1,398
Operating (loss) income															6,666
Interest expense, net															111
Other expense, net															-40
Net income (loss) before income tax expense															6,595
Year ended December 31, 2013
Gain on reversal of contingent consideration															0
Water and Environmental Services [Member]
Segment Reporting Information [Line Items]
Revenue												22,416	22,232		619
Costs of services												8,617	7,347		309
Gross margin												13,799	14,885		310
General and administrative expense												3,090	3,292		-4
Impairments												32,546	3,429
Depreciation, amortization and accretion												3,806	3,837		99
Operating (loss) income												-25,643	4,327		215
Total Assets	50,296				81,403					79,990		50,296	81,403		79,990
Pipeline Inspection and Integrity Services [Member]
Segment Reporting Information [Line Items]
Revenue												382,002	226,901		0
Costs of services												346,738	206,343		0
Gross margin												35,264	20,558		0
General and administrative expense												17,734	9,175		0
Impairments												0	702
Depreciation, amortization and accretion												2,539	1,327		0
Operating (loss) income												14,991	9,354		0
Total Assets	136,224				154,352					0		136,224	154,352		0
Other Segments [Member]
Segment Reporting Information [Line Items]
Revenue													0		0
Costs of services												0	0		0
Gross margin												0	0		0
General and administrative expense												497	0		2,060
Impairments												0	0
Depreciation, amortization and accretion												0	0		0
Operating (loss) income												-497	0		-2,060
Total Assets	$3,322				$4,835					$0		$3,322	$4,835		$0
[1]	Recast - Note 2

Note_16_Distributions_Details_

Note 16 - Distributions (Details) - Distributions Paid (USD $)	12 Months Ended
In Thousands, except Per Share data, unless otherwise specified	Dec. 31, 2014
Note 16 - Distributions (Details) - Distributions Paid [Line Items]
Per Unit Cash Distributions	$1.51
Total Cash Distributions	$17,870
Subsequent Event [Member] | Cash Distribution Q1 [Member]
Note 16 - Distributions (Details) - Distributions Paid [Line Items]
Payment Date	14-Feb-15	[1]
Per Unit Cash Distributions	$0.41	[1]
Total Cash Distributions	4,806	[1]
Cash Distribution Q2 [Member]
Note 16 - Distributions (Details) - Distributions Paid [Line Items]
Payment Date	15-May-14	[2]
Per Unit Cash Distributions	$0.30	[2]
Total Cash Distributions	3,565	[2]
Cash Distribution Q3 [Member]
Note 16 - Distributions (Details) - Distributions Paid [Line Items]
Payment Date	14-Aug-14
Per Unit Cash Distributions	$0.40
Total Cash Distributions	4,693
Cash Distribution Q4 [Member]
Note 16 - Distributions (Details) - Distributions Paid [Line Items]
Payment Date	14-Nov-14
Per Unit Cash Distributions	$0.41
Total Cash Distributions	4,806
Cash Distribution Paid in Current Year [Member]
Note 16 - Distributions (Details) - Distributions Paid [Line Items]
Per Unit Cash Distributions	$1.10
Total Cash Distributions	$13,064
[1]	Fourth quarter 2014 distribution was declared and paid in 2015.
[2]	Distribution was pro-rated from the date of our IPO through March 31, 2015.

Note_17_Subsequent_Events_Deta

Note 17 - Subsequent Events (Details) (USD $)	0 Months Ended		3 Months Ended
In Millions, unless otherwise specified	Feb. 01, 2015	1-May-15	Mar. 31, 2015
Subsequent Event [Member] | Tir Entities [Member]
Note 17 - Subsequent Events (Details) [Line Items]
Subsidiary of Limited Liability Company or Limited Partnership, Ownership Interest	49.90%
Payments to Acquire Businesses, Gross	$52.60
Business Acquisition, Percentage of Voting Interests Acquired	100.00%
Subsequent Event [Member] | Hydrostatic Business [Member]
Note 17 - Subsequent Events (Details) [Line Items]
Subsidiary of Limited Liability Company or Limited Partnership, Ownership Interest		51.00%
Payments to Acquire Businesses, Gross		10.7
Business Combination, Contingent Consideration Arrangements, Change in Range of Outcomes, Contingent Consideration, Liability, Value, High		9.5
Subsidiary of Limited Liability Company or Limited Partnership Right to Purchase Ownership Interest		49.00%
Business Combination Maximum Purchase Price of Remaining Ownership Interest		28
Scenario, Forecast [Member]
Note 17 - Subsequent Events (Details) [Line Items]
Increase Decrease in Management Fee Revenue from Prior Comparative Period			$0.30

Note_18_Condensed_Consolidatin2

Note 18 - Condensed Consolidating Financial Statements (Details) - Condensed Consolidating Balance Sheets (USD $)	Dec. 31, 2014	Dec. 31, 2013		Dec. 31, 2012		Mar. 14, 2012
In Thousands, unless otherwise specified
Current assets:
Cash and cash equivalents	$20,757	$26,690	[1]	$484	[1]	$0	[1]
Trade accounts receivable, net	54,075	60,730	[1]
Receivables from affiliates	0	0
Deferred tax assets	68	134	[1]
Deferred offering costs	0	2,539	[1]
Prepaid expenses and other	2,440	1,458	[1]
Total current assets	77,340	91,551	[1]
Property and equipment:
Property and equipment, at cost	27,878	42,529	[1]
Less: Accumulated depreciation	3,538	3,711	[1]
Total property and equipment, net	24,340	38,818	[1]
Intangible assets, net	30,245	32,551	[1]
Goodwill	55,545	75,466	[1]	33,877
Investment in subsidiaries	0
Notes receivable - affiliates	0	0
Debt issuance costs, net	2,318	2,149	[1]
Other assets	54	55	[1]
Total assets	189,842	240,590	[1]
Current liabilities:
Accounts payable	2,461	2,673	[1]
Accounts payable - affiliates	586	0	[1]
Accrued payroll and other	7,750	10,662	[1]
Income taxes payable	546	16,158	[1]
Total current liabilities	11,343	29,493	[1]
Long-term debt	77,600	75,000	[1]
Notes payable - affiliates		0
Commitments and contingencies	0		[1]
Deferred tax liabilities	438	541	[1]
Asset retirement obligations	33	9	[1]
Total liabilities	89,414	105,043	[1]
Owners' equity:
Total partners' capital	73,855	4,816	[1]
Non-controlling interests	26,573	0	[1]
Total parent net investment and owners' equity	100,428	135,547	[1]
Total liabilities, parent net investment and owners' equity	189,842	240,590	[1]
Reportable Legal Entities [Member] | Parent Company [Member]
Current assets:
Cash and cash equivalents	982	0		0
Trade accounts receivable, net	0	0
Receivables from affiliates	22	0
Deferred tax assets	0	0
Deferred offering costs		2,539
Prepaid expenses and other	0	147
Total current assets	1,004	2,686
Property and equipment:
Property and equipment, at cost	0	0
Less: Accumulated depreciation	0	0
Total property and equipment, net	0	0
Intangible assets, net	0	0
Goodwill	0	0
Investment in subsidiaries	98,965
Notes receivable - affiliates	0	0
Debt issuance costs, net	2,318	2,149
Other assets	0	0
Total assets	102,287	4,835
Current liabilities:
Accounts payable	34	0
Accounts payable - affiliates	0	0
Accrued payroll and other	6	19
Income taxes payable	0	0
Total current liabilities	40	19
Long-term debt	0	0
Notes payable - affiliates		0
Commitments and contingencies	0
Deferred tax liabilities	0	0
Asset retirement obligations	0	0
Total liabilities	40	19
Owners' equity:
Total partners' capital	75,764
Non-controlling interests	26,483
Total parent net investment and owners' equity	102,247	4,816
Total liabilities, parent net investment and owners' equity	102,287	4,835
Reportable Legal Entities [Member] | Guarantor Subsidiaries [Member]
Current assets:
Cash and cash equivalents	16,598	24,606		484
Trade accounts receivable, net	49,569	53,684
Receivables from affiliates	8,809	8,045
Deferred tax assets	15	0
Deferred offering costs		0
Prepaid expenses and other	2,339	1,281
Total current assets	77,330	87,616
Property and equipment:
Property and equipment, at cost	27,769	42,442
Less: Accumulated depreciation	3,485	3,690
Total property and equipment, net	24,284	38,752
Intangible assets, net	28,414	30,373
Goodwill	53,915	73,687
Notes receivable - affiliates	3,903	3,903
Debt issuance costs, net	0	0
Other assets	35	48
Total assets	187,881	234,379
Current liabilities:
Accounts payable	2,161	1,708
Accounts payable - affiliates	586	0
Accrued payroll and other	7,605	10,544
Income taxes payable	507	14,988
Total current liabilities	10,859	27,240
Long-term debt	77,600	75,000
Notes payable - affiliates		0
Commitments and contingencies	0
Deferred tax liabilities	0	0
Asset retirement obligations	33	9
Total liabilities	88,492	102,249
Owners' equity:
Total partners' capital	98,380
Non-controlling interests	1,009
Total parent net investment and owners' equity	99,389	132,130
Total liabilities, parent net investment and owners' equity	187,881	234,379
Reportable Legal Entities [Member] | Non-Guarantor Subsidiaries [Member]
Current assets:
Cash and cash equivalents	3,177	2,084		0
Trade accounts receivable, net	4,514	7,046
Receivables from affiliates	0	0
Deferred tax assets	53	134
Deferred offering costs		0
Prepaid expenses and other	101	30
Total current assets	7,845	9,294
Property and equipment:
Property and equipment, at cost	109	87
Less: Accumulated depreciation	53	21
Total property and equipment, net	56	66
Intangible assets, net	1,831	2,178
Goodwill	1,630	1,779
Investment in subsidiaries	0
Notes receivable - affiliates	0	0
Debt issuance costs, net	0	0
Other assets	19	6
Total assets	11,381	13,323
Current liabilities:
Accounts payable	266	965
Accounts payable - affiliates	8,839	8,044
Accrued payroll and other	139	99
Income taxes payable	39	1,170
Total current liabilities	9,283	10,278
Long-term debt	0	0
Notes payable - affiliates		3,795
Commitments and contingencies	3,479
Deferred tax liabilities	438	541
Asset retirement obligations	0	0
Total liabilities	13,200	14,614
Owners' equity:
Total partners' capital	-1,819
Total parent net investment and owners' equity	-1,819	-1,291
Total liabilities, parent net investment and owners' equity	11,381	13,323
Consolidation, Eliminations [Member]
Current assets:
Cash and cash equivalents	0	0		0
Trade accounts receivable, net	-8	0
Receivables from affiliates	-8,831	-8,045
Deferred tax assets	0	0
Deferred offering costs		0
Prepaid expenses and other	0	0
Total current assets	-8,839	-8,045
Property and equipment:
Property and equipment, at cost	0	0
Less: Accumulated depreciation	0	0
Total property and equipment, net	0	0
Intangible assets, net	0	0
Goodwill	0	0
Investment in subsidiaries	-98,965
Notes receivable - affiliates	-3,903	-3,903
Debt issuance costs, net	0	0
Other assets	0	1
Total assets	-111,707	-11,947
Current liabilities:
Accounts payable	0	0
Accounts payable - affiliates	-8,839	-8,044
Accrued payroll and other	0	0
Income taxes payable	0	0
Total current liabilities	-8,839	-8,044
Long-term debt	0	0
Notes payable - affiliates		-3,795
Commitments and contingencies	-3,479
Deferred tax liabilities	0	0
Asset retirement obligations	0	0
Total liabilities	-12,318	-11,839
Owners' equity:
Total partners' capital	-98,470
Non-controlling interests	-919
Total parent net investment and owners' equity	-99,389	-108
Total liabilities, parent net investment and owners' equity	($111,707)	($11,947)
[1]	Recast - Note 2

Note_18_Condensed_Consolidatin3

Note 18 - Condensed Consolidating Financial Statements (Details) - Condensed Consolidating Statements of Operations (USD $)	3 Months Ended								10 Months Ended		12 Months Ended
In Thousands, unless otherwise specified	Dec. 31, 2014	Sep. 30, 2014	Jun. 30, 2014	Mar. 31, 2014	Dec. 31, 2013	Sep. 30, 2013	Jun. 30, 2013	Mar. 31, 2013	Dec. 31, 2012		Dec. 31, 2014	Dec. 31, 2013		Dec. 31, 2012
Condensed Income Statements, Captions [Line Items]
Revenues	$102,157	$111,016	$93,722	$97,523	$117,640	$116,980	$9,176	$5,337	$619		$404,418	$249,133	[1]	$619
Costs of services									309		355,355	213,690	[1]	309
Gross margin	12,059	13,281	12,303	11,420	13,652	14,311	3,725	3,755	310		49,063	35,443	[1]	310
Operating costs and expense:
General and administrative									2,056		21,321	12,467	[1]	2,056
Depreciation, amortization and accretion									99		6,345	5,164	[1]
Impairments									0	[1]	32,546	4,131	[1]
Operating income									-1,845		-11,149	13,681	[1]	-1,845
Other income (expense):
Equity earnings (loss) in subsidiaries											0	0
Interest expense, net											-3,208	-4,000	[1]
Offering costs											-446	-1,376	[1]
Gain on reversal of contingent consideration							11,250		0	[1]	0	11,250	[1]
Other, net											92	37	[1]
Net income (loss) before income tax expense									-1,845		-14,711	19,592	[1]
Income tax expense					13,973	1,211	53				468	15,237	[1]	0
Net income (loss)	-28,722	5,097	4,929	3,517	-15,188	4,488	12,824	2,231	-1,845	[1]	-15,179	4,355	[1]	-1,845
Net income attributable to non-controlling interests											4,973	22	[1]
Net income (loss) attributable to controlling interests											-20,152	4,333	[1]
Reportable Legal Entities [Member] | Parent Company [Member]
Condensed Income Statements, Captions [Line Items]
Revenues											0	0
Costs of services											0	0
Gross margin											0	0
Operating costs and expense:
General and administrative											0	0
Depreciation, amortization and accretion											0	0
Impairments											0	0
Operating income											0	0
Other income (expense):
Equity earnings (loss) in subsidiaries											-14,134	0
Interest expense, net											-983	-18
Offering costs											-446	-1,376
Gain on reversal of contingent consideration												0
Other, net											0	0
Net income (loss) before income tax expense											-15,563	-1,394
Income tax expense											0	0
Net income (loss)											-15,563	-1,394
Net income attributable to non-controlling interests											4,646	0
Net income (loss) attributable to controlling interests											-20,209	-1,394
Reportable Legal Entities [Member] | Guarantor Subsidiaries [Member]
Condensed Income Statements, Captions [Line Items]
Revenues											370,081	222,250
Costs of services											323,821	188,928
Gross margin											46,260	33,322
Operating costs and expense:
General and administrative											19,257	11,283
Depreciation, amortization and accretion											6,136	5,027
Impairments											32,546	3,429
Operating income											-11,679	13,583
Other income (expense):
Interest expense, net											-1,892	-3,822
Offering costs											0	0
Gain on reversal of contingent consideration												11,250
Other, net											84	41
Net income (loss) before income tax expense											-13,487	21,052
Income tax expense											356	14,187
Net income (loss)											-13,843	6,865
Net income attributable to non-controlling interests											291	22
Net income (loss) attributable to controlling interests											-14,134	6,843
Reportable Legal Entities [Member] | Non-Guarantor Subsidiaries [Member]
Condensed Income Statements, Captions [Line Items]
Revenues											34,337	26,883
Costs of services											31,534	24,762
Gross margin											2,803	2,121
Operating costs and expense:
General and administrative											2,064	1,184
Depreciation, amortization and accretion											209	137
Impairments											0	702
Operating income											530	98
Other income (expense):
Equity earnings (loss) in subsidiaries											0	0
Interest expense, net											-333	-160
Offering costs											0	0
Gain on reversal of contingent consideration												0
Other, net											8	-4
Net income (loss) before income tax expense											205	-66
Income tax expense											112	1,050
Net income (loss)											93	-1,116
Net income attributable to non-controlling interests												0
Net income (loss) attributable to controlling interests											93	-1,116
Consolidation, Eliminations [Member]
Condensed Income Statements, Captions [Line Items]
Revenues											0	0
Costs of services											0	0
Gross margin											0	0
Operating costs and expense:
General and administrative											0	0
Depreciation, amortization and accretion											0	0
Impairments											0	0
Operating income											0	0
Other income (expense):
Equity earnings (loss) in subsidiaries											14,134
Interest expense, net											0	0
Offering costs											0	0
Gain on reversal of contingent consideration												0
Other, net											0	0
Net income (loss) before income tax expense											14,134
Income tax expense											0	0
Net income (loss)											14,134
Net income attributable to non-controlling interests											36	0
Net income (loss) attributable to controlling interests											$14,098
[1]	Recast - Note 2

Note_18_Condensed_Consolidatin4

Note 18 - Condensed Consolidating Financial Statements (Details) - Condensed Consolidating Statements of Comprehensive Income (Loss) (USD $)	3 Months Ended								10 Months Ended		12 Months Ended
In Thousands, unless otherwise specified	Dec. 31, 2014	Sep. 30, 2014	Jun. 30, 2014	Mar. 31, 2014	Dec. 31, 2013	Sep. 30, 2013	Jun. 30, 2013	Mar. 31, 2013	Dec. 31, 2012		Dec. 31, 2014	Dec. 31, 2013		Dec. 31, 2012
Condensed Statement of Income Captions [Line Items]
Net income (loss)	($28,722)	$5,097	$4,929	$3,517	($15,188)	$4,488	$12,824	$2,231	($1,845)	[1]	($15,179)	$4,355	[1]	($1,845)
Other comprehensive (loss):
Foreign currency translation									0		-937	-112	[1]
Comprehensive income (loss)									-1,845		-16,116	4,243	[1]
Comprehensive income (loss) attributable to non-controlling interests									0		4,658	22	[1]
Comprehensive income (loss) attributable to controlling interests									-1,845		-20,774	4,221	[1]
Reportable Legal Entities [Member] | Parent Company [Member]
Condensed Statement of Income Captions [Line Items]
Net income (loss)											-15,563	-1,394
Other comprehensive (loss):
Foreign currency translation											0	0
Comprehensive income (loss)											-15,563	-1,394
Comprehensive income (loss) attributable to non-controlling interests											4,646	0
Comprehensive income (loss) attributable to controlling interests											-20,209	-1,394
Reportable Legal Entities [Member] | Guarantor Subsidiaries [Member]
Condensed Statement of Income Captions [Line Items]
Net income (loss)											-13,843	6,865
Other comprehensive (loss):
Foreign currency translation											0	0
Comprehensive income (loss)											-13,843	6,865
Comprehensive income (loss) attributable to non-controlling interests											291	22
Comprehensive income (loss) attributable to controlling interests											-14,134	6,843
Reportable Legal Entities [Member] | Non-Guarantor Subsidiaries [Member]
Condensed Statement of Income Captions [Line Items]
Net income (loss)											93	-1,116
Other comprehensive (loss):
Foreign currency translation											-621	-112
Comprehensive income (loss)											-528	-1,228
Comprehensive income (loss) attributable to non-controlling interests												0
Comprehensive income (loss) attributable to controlling interests											-528	-1,228
Consolidation, Eliminations [Member]
Condensed Statement of Income Captions [Line Items]
Net income (loss)											14,134
Other comprehensive (loss):
Foreign currency translation											-316	0
Comprehensive income (loss)											13,818
Comprehensive income (loss) attributable to non-controlling interests											-279	0
Comprehensive income (loss) attributable to controlling interests											$14,097
[1]	Recast - Note 2

Note_18_Condensed_Consolidatin5

Note 18 - Condensed Consolidating Financial Statements (Details) - Condensed Consolidating Statements of Cash Flow (USD $)	12 Months Ended
In Thousands, unless otherwise specified	Dec. 31, 2014		Dec. 31, 2013		Dec. 31, 2012
Operating activities:
Net income (loss)	($15,179)		$4,355	[1]	($1,845)
Adjustments to reconcile net income (loss) to cash provided by (used in) operating activities:
Depreciation, amortization and accretion	6,513		5,261	[1]
Impairments	32,546		4,131	[1]
Gain on reversal of contingent consideration	0		-11,250	[1]
Loss on asset disposal	3		0	[1]
Interest expense from debt issuance cost amortization	714		1,219	[1]
Amortization of equity-based compensation	785		90	[1]
Equity earnings in investee company	-46		-32	[1]
Distributions from investee company	55		0	[1]
Equity earnings in subsidiaries	0		0
Deferred tax benefit, net	-13		-2,016	[1]
Non-cash allocated GP expenses	497		0	[1]
Changes in assets and liabilities:
Trade accounts receivable	6,650		-8,793	[1]
Prepaid expenses and other	-933		283	[1]
Accounts payable and accrued payroll and other	-2,964		-1,910	[1]
Income taxes payable	-15,612		15,816	[1]
Net cash provided by (used in) operating activities	13,016		7,154	[1]
Investing activities:
Cash acquired - TIR Entities	0		10,108	[1]
Investing activities:
Acquisition of businesses	-1,769		-500	[1]
Purchase of property and equipment	-517		-3,829	[1]
Net cash provided by (used in) investing activities	-2,286		5,779	[1]
Net payments on factoring agreement	0		-36,748	[1]
Payments on behalf of affiliates	0		-5,763	[1]
Purchase of non-controlling interests	0		-572	[1]
Tax benefit of stock options exercised	0		528	[1]
Financing activities:
Proceeds from initial public offering	80,213		0	[1]
Distribution of initial public offering proceeds to Cypress Energy Holdings, LLC	-80,213		0	[1]
Payment of deferred offering costs	-314		-2,539	[1]
Advances on long-term debt	7,600		75,000	[1]
Repayment of long-term debt	-5,000		-19,385	[1]
Payment of debt issuance costs	-883		-3,368	[1]
Contributions from general partner	-168		0	[1]
Net advances from members	482		6,210	[1]
Distributions from subsidiaries	0
Distributions to limited partners	-13,064		0	[1]
Distributions to non-controlling members of the TIR Entities	-4,683		0	[1]
Net cash provided by (used in) financing activities	-16,030		13,363	[1]
Effect of exchange rates on cash	-633		-90	[1]
Net increase (decrease) in cash and cash equivalents	-5,933		26,206	[1]
Cash and cash equivalents, beginning of period	26,690	[1]	484	[1]
Cash and cash equivalents, end of period	20,757		26,690	[1]	484	[1]
Non-cash items:
Accounts payable excluded from capital expenditures	756		330	[1]
Supplemental cash flow disclosures:
Cash taxes paid	16,674		817	[1]
Cash interest paid	2,415		3,917	[1]
Reportable Legal Entities [Member] | Parent Company [Member]
Operating activities:
Net income (loss)	-15,563		-1,394
Adjustments to reconcile net income (loss) to cash provided by (used in) operating activities:
Depreciation, amortization and accretion	0		0
Impairments	0		0
Gain on reversal of contingent consideration			0
Loss on asset disposal	0
Interest expense from debt issuance cost amortization	714		0
Amortization of equity-based compensation	785		0
Equity earnings in investee company	0		0
Distributions from investee company	0
Equity earnings in subsidiaries	14,134		0
Deferred tax benefit, net	0		0
Non-cash allocated GP expenses	0
Changes in assets and liabilities:
Trade accounts receivable	-22		0
Prepaid expenses and other	744		-147
Accounts payable and accrued payroll and other	21		19
Income taxes payable	0		0
Net cash provided by (used in) operating activities	813		-1,522
Investing activities:
Cash acquired - TIR Entities			0
Investing activities:
Acquisition of businesses	0		0
Purchase of property and equipment	0		0
Net cash provided by (used in) investing activities	0		0
Net payments on factoring agreement			0
Payments on behalf of affiliates			0
Purchase of non-controlling interests			0
Tax benefit of stock options exercised			0
Financing activities:
Proceeds from initial public offering	80,213
Distribution of initial public offering proceeds to Cypress Energy Holdings, LLC	-80,213
Payment of deferred offering costs	-314		-2,539
Advances on long-term debt	0		0
Repayment of long-term debt	0		0
Payment of debt issuance costs	-883		-2,149
Contributions from general partner	0		6,210
Net advances from members	-105
Distributions from subsidiaries	14,535
Distributions to limited partners	-13,064
Distributions to non-controlling members of the TIR Entities	0
Net cash provided by (used in) financing activities	169		1,522
Effect of exchange rates on cash	0		0
Net increase (decrease) in cash and cash equivalents	982		0
Cash and cash equivalents, beginning of period	0		0
Cash and cash equivalents, end of period	982		0
Non-cash items:
Accounts payable excluded from capital expenditures	0		0
Supplemental cash flow disclosures:
Cash taxes paid	0		0
Cash interest paid	0		0
Reportable Legal Entities [Member] | Guarantor Subsidiaries [Member]
Operating activities:
Net income (loss)	-13,843		6,865
Adjustments to reconcile net income (loss) to cash provided by (used in) operating activities:
Depreciation, amortization and accretion	6,337		5,124
Impairments	32,546		3,429
Gain on reversal of contingent consideration			-11,250
Loss on asset disposal	3
Interest expense from debt issuance cost amortization	0		1,219
Amortization of equity-based compensation	0		90
Equity earnings in investee company	-46		-32
Distributions from investee company	55
Deferred tax benefit, net	-15		-1,751
Non-cash allocated GP expenses	497
Changes in assets and liabilities:
Trade accounts receivable	4,145		-10,705
Prepaid expenses and other	-1,600		395
Accounts payable and accrued payroll and other	-3,121		-2,843
Income taxes payable	-14,481		14,417
Net cash provided by (used in) operating activities	10,477		4,958
Investing activities:
Cash acquired - TIR Entities			6,628
Investing activities:
Acquisition of businesses	-1,769		-500
Purchase of property and equipment	-517		-3,829
Net cash provided by (used in) investing activities	-2,286		2,299
Net payments on factoring agreement			-36,748
Payments on behalf of affiliates			-5,763
Purchase of non-controlling interests			-572
Tax benefit of stock options exercised			528
Financing activities:
Proceeds from initial public offering	0
Distribution of initial public offering proceeds to Cypress Energy Holdings, LLC	0
Payment of deferred offering costs	0		0
Advances on long-term debt	7,600		75,000
Repayment of long-term debt	-5,000		-14,361
Payment of debt issuance costs	0		-1,219
Contributions from general partner	-168		0
Net advances from members	587
Distributions from subsidiaries	-14,535
Distributions to limited partners	0
Distributions to non-controlling members of the TIR Entities	-4,683
Net cash provided by (used in) financing activities	-16,199		16,865
Effect of exchange rates on cash	0		0
Net increase (decrease) in cash and cash equivalents	-8,008		24,122
Cash and cash equivalents, beginning of period	24,606		484
Cash and cash equivalents, end of period	16,598		24,606
Non-cash items:
Accounts payable excluded from capital expenditures	756		330
Supplemental cash flow disclosures:
Cash taxes paid	16,420		717
Cash interest paid	2,415		3,917
Reportable Legal Entities [Member] | Non-Guarantor Subsidiaries [Member]
Operating activities:
Net income (loss)	93		-1,116
Adjustments to reconcile net income (loss) to cash provided by (used in) operating activities:
Depreciation, amortization and accretion	176		137
Impairments	0		702
Gain on reversal of contingent consideration			0
Loss on asset disposal	0
Interest expense from debt issuance cost amortization	0		0
Amortization of equity-based compensation	0		0
Equity earnings in investee company	0		0
Distributions from investee company	0
Equity earnings in subsidiaries	0		0
Deferred tax benefit, net	2		-265
Non-cash allocated GP expenses	0
Changes in assets and liabilities:
Trade accounts receivable	2,527		1,912
Prepaid expenses and other	-77		35
Accounts payable and accrued payroll and other	136		914
Income taxes payable	-1,131		1,399
Net cash provided by (used in) operating activities	1,726		3,718
Investing activities:
Cash acquired - TIR Entities			3,480
Investing activities:
Acquisition of businesses	0		0
Purchase of property and equipment	0		0
Net cash provided by (used in) investing activities	0		3,480
Net payments on factoring agreement			0
Payments on behalf of affiliates			0
Purchase of non-controlling interests			0
Tax benefit of stock options exercised			0
Financing activities:
Proceeds from initial public offering	0
Distribution of initial public offering proceeds to Cypress Energy Holdings, LLC	0
Payment of deferred offering costs	0		0
Advances on long-term debt	0		0
Repayment of long-term debt	0		-5,024
Payment of debt issuance costs	0		0
Contributions from general partner	0		0
Net advances from members	0
Distributions from subsidiaries	0
Distributions to limited partners	0
Distributions to non-controlling members of the TIR Entities	0
Net cash provided by (used in) financing activities	0		-5,024
Effect of exchange rates on cash	-633		-90
Net increase (decrease) in cash and cash equivalents	1,093		2,084
Cash and cash equivalents, beginning of period	2,084		0
Cash and cash equivalents, end of period	3,177		2,084
Non-cash items:
Accounts payable excluded from capital expenditures	0		0
Supplemental cash flow disclosures:
Cash taxes paid	254		100
Cash interest paid	0		0
Consolidation, Eliminations [Member]
Operating activities:
Net income (loss)	14,134
Adjustments to reconcile net income (loss) to cash provided by (used in) operating activities:
Depreciation, amortization and accretion	0		0
Impairments	0		0
Gain on reversal of contingent consideration			0
Loss on asset disposal	0
Interest expense from debt issuance cost amortization	0		0
Amortization of equity-based compensation	0		0
Equity earnings in investee company	0		0
Distributions from investee company	0
Equity earnings in subsidiaries	-14,134
Deferred tax benefit, net	0		0
Non-cash allocated GP expenses	0
Changes in assets and liabilities:
Trade accounts receivable	0		0
Prepaid expenses and other	0		0
Accounts payable and accrued payroll and other	0		0
Income taxes payable	0		0
Net cash provided by (used in) operating activities	0		0
Investing activities:
Cash acquired - TIR Entities			0
Investing activities:
Acquisition of businesses	0		0
Purchase of property and equipment	0		0
Net cash provided by (used in) investing activities	0
Net payments on factoring agreement			0
Payments on behalf of affiliates			0
Purchase of non-controlling interests			0
Tax benefit of stock options exercised			0
Financing activities:
Proceeds from initial public offering	0
Distribution of initial public offering proceeds to Cypress Energy Holdings, LLC	0
Payment of deferred offering costs	0		0
Advances on long-term debt	0		0
Repayment of long-term debt	0		0
Payment of debt issuance costs	0		0
Contributions from general partner	0		0
Net advances from members	0
Distributions from subsidiaries	0
Distributions to limited partners	0
Distributions to non-controlling members of the TIR Entities	0
Net cash provided by (used in) financing activities	0		0
Effect of exchange rates on cash	0		0
Net increase (decrease) in cash and cash equivalents	0		0
Cash and cash equivalents, beginning of period	0		0
Cash and cash equivalents, end of period	0		0
Non-cash items:
Accounts payable excluded from capital expenditures	0		0
Supplemental cash flow disclosures:
Cash taxes paid	0		0
Cash interest paid	$0		$0
[1]	Recast - Note 2

Quarterly_Financial_Informatio2

Quarterly Financial Information (unaudited) (Details) - Quarterly Financial Information (unaudited) (USD $)	3 Months Ended								10 Months Ended		12 Months Ended
In Thousands, except Per Share data, unless otherwise specified	Dec. 31, 2014	Sep. 30, 2014	Jun. 30, 2014	Mar. 31, 2014	Dec. 31, 2013	Sep. 30, 2013	Jun. 30, 2013	Mar. 31, 2013	Dec. 31, 2012		Dec. 31, 2014	Dec. 31, 2013		Dec. 31, 2012
Quarterly Financial Information (unaudited) [Abstract]
Revenues	$102,157	$111,016	$93,722	$97,523	$117,640	$116,980	$9,176	$5,337	$619		$404,418	$249,133	[1]	$619
Gross margin	12,059	13,281	12,303	11,420	13,652	14,311	3,725	3,755	310		49,063	35,443	[1]	310
Impairments	32,546				4,131
Gain on reversal of contingent consideration							11,250		0	[1]	0	11,250	[1]
Income tax expense					13,973	1,211	53				468	15,237	[1]	0
Net income (loss)	-28,722	5,097	4,929	3,517	-15,188	4,488	12,824	2,231	-1,845	[1]	-15,179	4,355	[1]	-1,845
Net income (loss) attributable to partners / controlling interests	($30,131)	$3,555	$3,680	$2,744	($15,210)	$4,488	$12,824	$2,231
Net income (loss) per common limited partner unit – basic (in Dollars per share)	($2.51)	$0.30	$0.31	$0.18
Net income (loss) per common limited partner unit – diluted (in Dollars per share)	($2.51)	$0.30	$0.31	$0.17
Net income (loss) per subordinated limited partner unit –basic and diluted (in Dollars per share)	($2.51)	$0.30	$0.31	$0.18
[1]	Recast - Note 2